IFI / LCNF REPORT April 2010 to March 2011

For the licensed companies: Eastern Power Networks plc London Power Networks plc South Eastern Power Networks plc

Welcome to the UK Power Networks annual report describing our activities under Ofgem’s Innovation Funding Incentive (IFI). This is the first report since UK Power Networks took ownership of the distribution licences of Eastern Power Networks plc, London Power Networks plc, and South Eastern Power Networks plc, which were previously owned by EDF Energy. You can see the area we serve and a high level view of our business on page 3.

This report demonstrates our new shareholders’ strong commitment to innovation. We recognise that innovation brings about improvements in performance for our customers, continual improvement in the way that we work internally, brings our employees into contact with the latest technologies and is an essential element to making the energy sector a compelling place to work.

I am proud to say that this report represents only a small portion of our innovation activities. We relished the opportunity to present both our Low Carbon London project and our Low Carbon Network Fund (Tier 1)-funded trials to our fellow Distribution Network Operators, Ofgem, and an invited audience of manufacturers and stakeholders at the recent annual Low Carbon Network Fund conference. This will be a central place for debate in the coming years about the right technologies and right commercial approaches to building the electricity network for a Low Carbon economy.

Separately, you may have seen the recent press release regarding our work with the Energy Technologies Institute to develop a novel Fault Current Limiter. Currently at an early stage in their development, Fault Current Limiters have the potential to build greater flexibility into our existing networks, and the potential to allow embedded generation to connect to our network quickly and cost-effectively where otherwise an upgrade or replacement of our existing plant might have been required.

The part of our innovation portfolio presented in this report therefore has two particular emphases: the first is on the early-stage, often desktop studies required to think through new and novel ideas across the full spectrum of challenges. The second emphasis is on the development of technology which can make a step change in our core commitments to provide safe, reliable and efficient electricity supplies to existing customers and timely, cost- effective connections to new customers. The highlights on pages 7 – 12 range a span of improvements to the way in which we detect, maintain and respond to the health of assets, use more and richer information in our decisions, and to investigate further ways to build flexible capacity. We are particularly proud to have commissioned the energy storage device at Hemsby in recent months.

Enjoy the report!

Basil Scarsella Chief Executive Officer, UK Power Networks

Contents

Introduction 2 Highlights 9 Individual Project Reports 15 Future Networks Scenarios 17 Smart Management of Assets 33 Visible Flexible Networks 61 Full Fault Knowledge 73 Optimal Network Operation 83

1 Introduction UK Power Networks operates the electricity distribution network for three licence areas, London, the East of England and the South-East of England. We run an electricity distribution infrastructure supporting eight million customers and including significant business and critical infrastructure in London.

Our aims are to deliver both quality and value to electricity customers by investing wisely and cost- effectively in infrastructure, offering timely connections to our network, and maintaining high standards of supply. In parallel, we have a core challenge to support the transition to a low-carbon economy. The UK government’s Low Carbon Transition Plan1 outlines an intention to generate 30% of electricity from renewables, 12% of heat from renewable sources and to drive 10% of transport to renewable sources by 2020.

Increasing the use of electric vehicles charged from the distribution network and an increase in electric heating supplied by the distribution network will be fundamental to achieving these targets. UK Power Networks recognises that it needs to build on its understanding now of how electricity demand will change and investigate new tools and design options to add to our armoury in order to support this increased demand.

Innovation is central to these challenges.

This report is our annual summary to our regulator, the Office of the Gas and Electricity Markets (Ofgem), of innovation activities which have been funded by the Innovation Funding Incentive (IFI). We are also aware that a number of other stakeholders will be reading this report in order to understand our activities. For this reason, we provide some initial context by introducing the company, our approach to innovation and the background to the IFI.

Company Structure UK Power Networks owns and operates the licensed distribution networks serving the East of England, London and the South-East of England. The licensees managed by UK Power Networks are:

 Eastern Power Networks plc for the East of England, referred to as ‘EPN’ in the rest of this report.  London Power Networks plc for London, referred to as ‘LPN’ in the rest of this report.  South-Eastern Power Networks plc for the South-east of England, referred to as ‘SPN’ in the rest of this report.

These licence areas are shown in the map on page 3.

1 ’The UK Low Carbon Transition Plan: National Strategy for Climate and Energy‘, published 2009 by the Department for Energy and Climate Change. ISBN 9780108508394.

2 EPN

LPN

SPN

Innovation activities are conducted by UK Power Networks on behalf of EPN LPN and SPN for the benefit of our customers in these licence areas. We allocate expenditure to each licence area operator in proportion to the major asset associated with the benefits expected from each individual project; for example, our innovation projects which are focussed on overhead lines are largely funded from the IFI allowance allocated to EPN and SPN, where the majority of our overhead line network is found.

Our innovation activities typically fall into a number of categories; either to understand a future issue and build a timeline for action or to inform engineering policy decisions; or to develop new solutions such as test equipment, sensors, network management controllers, network management software and desktop design tools.

UK Power Networks runs a balanced portfolio of innovation projects in order to take an informed approach and projects range from early-stage research through to trials on our network. The IFI has been a significant source of funding for our innovation activities, but we seek to leverage other sources of funding where possible. In parallel with the activities reported here, UK Power Networks is strongly involved with Ofgem’s Low Carbon Network Fund (LCNF). UK Power Networks was awarded funding during 2010 for its Low Carbon London project and for two Tier 1 projects, details of which can be found on the Ofgem’s website and which are discussed on pages 11 and 12.

3 Background to the Innovation Funding Incentive The primary aim of the IFI is to encourage both distribution and transmission network operators to apply innovation in the technical development of their networks. Ofgem recognises that innovation has a different risk/reward balance compared with a network operator’s core business. The incentives provided by the IFI mechanism are designed to create a risk/reward balance that is consistent with research, development, demonstration and deployment.

IFI is intended to provide funding for projects primarily focused on the technical development of the networks, to deliver value (e.g. financial, quality of supply, environmental, safety) to end consumers.

The IFI activities described in this report are governed by Standard Licence Condition 46 and Charge Restriction Condition 10 in the electricity distribution licence. Their requirements can be summarised as follows:  A network operator is allowed to spend up to 0.5% of its combined distribution network revenue or its combined transmission network revenue, as the case maybe, on eligible IFI projects.  Internal expenditure incurred by the network operator in running and implementing IFI projects can be considered as part of the total IFI expenditure accrued by the network operator.  The network operator is allowed to recover 80% of its eligible project expenditure via the IFI mechanism within the network operator’s licence.  Ofgem will not approve IFI projects but network operators will have to openly report their IFI activities on an annual basis. This report constitutes UK Power Networks’ annual report on our activities from 1 April 2010 to 31 March 2011 and will be published on the Ofgem website alongside those of other network operators.  Ofgem reserves the right to audit IFI activities if this is judged to be necessary in the interests of customers.

Eligibility for IFI Funding Projects will be judged as eligible within the IFI, provided that:  The project satisfies the eligibility criteria described in Engineering Recommendation G85, Issue 2, ‘Innovation Good Practice Guide for Energy Networks’, published by the Energy Networks Association (ENA).  The project has been well managed.  Reporting requirements have been met.

This report is intended to fulfil our reporting requirements and to demonstrate that our projects are being well managed. Each individual project report presented later includes a project ‘score’ which summarises how the project meets the eligibility criteria laid down in Engineering Recommendation G85.

Work that has been approved within an industry recognised or national/governmental programme (such as a Technology Strategy Board programme or European Commission programme) and whose terms of reference clearly address innovation in the networks maybe considered eligible within IFI if it meets the defined criteria. Co-operation between network operators and other organisations to pursue IFI projects is encouraged. In such cases the overall project would be expected to meet the IFI eligibility criteria and it would then be acceptable for each participating network operator to use the eligibility case for the overall project. IFI projects that secure additional funding from outside agencies, such as the Technology Strategy Board or the European Commission, will not trigger any claw-back of IFI funding by Ofgem. Engagement with industry engineering committees is not considered eligible as this does not constitute a project with a specific target or deliverable.

In the event that a network operator provides resources to contribute to an eligible IFI project which is led or managed by a third party, those costs incurred by the network operator, that are not recovered from the third party will be considered to be eligible IFI expenditure. Where supporting such projects with a net cost to the network operator, the network operator should demonstrate that the expected benefits to the network operator exceed the costs involved.

IFI projects, by their nature, involve risk. It is understood, therefore, that not all IFI projects will meet their aims and objectives and deliver net benefits. However, it is expected that the benefits from those that do succeed will significantly exceed the overall costs of a network operator’s IFI programme.

4 Summary of Expenditure

The table and figure below show UK Power Networks’ usage of the innovation funding incentive since its inception: IFI Expenditure 6

5

4 Total £M expenditure 3 Allowance 2

1 0 early 05-06 06-07 07-08 08-09 09-10 10-11 start Regulatory Year

Regulatory year Total expenditure This regulatory year 10/11 £3,339.5k Regulatory year 09/10 £3,545.2k Regulatory year 08/09 £3,922.6k Regulatory year 07/08 £4,993.5k Regulatory year 06/07 £3,575.8k Regulatory year 05/06 £2,570.9k Early start report 04/05 £ 275.8k Total £22,223.3k

Details of the expenditure in the current regulatory year are shown below:

EPN LPN SPN TOTAL IFI carry forward from 09/10 (£k) £180.1k £545.9k £189.4k £915.4k Combined distribution network revenue (£m) £381.4m £329.7m £247.5m £958.6m Allowance 10/11 (£k) £2,087.1k £2,194.4k £1,426.9k £5,708.4k Eligible IFI expenditure 10/11(£k) £1,451.6k £1,023.8k £864.1k £3,339.5k Of which internal expenditure 10/11(£k) £196.7k £97.6k £78.5k £372.8k The IFI carry forward to 2011/12 (£k) £417.1k £624.7k £373.7k £1,415.4k

5 Expenditure from IFI Projects

The table below details individual project spends from April 2010 to March 2011. Spend for a project has been proportioned across UK Power Networks’ three licence areas according to the number of assets in each area most likely to benefit from the research outcomes. The basis of the allocation is specified in each project report. EPN LPN SPN Total Future Networks Scenarios Growth in City Centres £0 £105,317 £0 £105,317 Bankside Heat Transfer £0 £36,575 £0 £36,575 Feasibility of an Active Network Management £19,454 £5,887 £12,910 £38,250 Solution International DSM Survey £15,860 £10,136 £10,142 £36,138 High Performance Computing Technologies for Smart Distributed Network Operation £1,231 £787 £787 £2,805 (HiPerDNO) Supergen 3 – HiDef Highly Distributed Energy £10,132 £6,475 £6,479 £23,086 Futures Smart Management of Assets On-Line Condition Monitoring £29,672 £306,612 £158,252 £494,536 Advanced Management of Tap Changers £94,501 £39,506 £52,178 £186,185 Intelligent Condition Monitoring and Diagnosis £50,933 £17,326 £39,661 £107,920 Understanding Ageing Mechanisms in XLPE £19,004 £8,545 £10,702 £38,250 cables Condition Monitoring of Composite Insulators £28,769 £0 £8,374 £37,143 Grid Transformer Monitoring £10,727 £4,484 £5,923 £21,134 Supergen V – AMPerES £149 £95 £95 £340 Power Networks Research Academy £43,860 £28,029 £28,048 £99,937 Vegetation Management £47,862 £22 £17,156 £65,041 Tree Growth Regulator £14,279 £7 £5,118 £19,403 GIS Data Definition £159,466 £0 £0 £159,466 Transformer Oil Health Index Tool £11,058 £4,623 £6,106 £21,786 Visible Flexible Networks AURA NMS – Autonomous Regional Active £392,441 £277,653 £252,556 £922,678 Network Management System Supergen 1 - FlexNet £9,657 £6,171 £6,175 £22,003 Algorithmic Automation £5,188 £3,316 £3,318 £11,821 The Zefal Generator for Active Urban Networks £0 £10,026 £0 £10,026 (ZEFAL) Full Fault Knowledge LV Remote Control and Automation £24,276 £13,884 £16,003 £54,163 Overhead Line Incipient Fault Detection £66,248 £31 £23,746 £90,026 Helicopter Mounted Partial Discharge Locator £22,967 £11 £8,232 £31,210 LV Underground Cable Fault Management £15,372 £8,792 £10,133 £34,297 Optimal Network Operation Optimal Transformer Utilisation £172 £72 £95 £340 Strategic Technology Programme: Module 2: Overhead Networks £17,813 £0 £5,321 £23,134 Module 3: Cable Networks £12,470 £7,652 £8,219 £28,340 Module 4: Substations £14,156 £4,333 £10,400 £28,889 Module 5: Networks for Distributed Energy £13,273 £5,254 £9,125 £27,653 Resources

6 Collaborative ENA R&D Programme £31,666 £20,237 £20,250 £72,154 Network Risk Management £65,751 £42,019 £42,047 £149,816 Active Distribution networks with full integration of Demand and distributed energy RESourseS £149 £95 £95 £340 (ADDRESS) Transformer Design for FR3 £48,174 £0 £0 £48,174 Vacuum Tap Changers £997 £417 £551 £1,965 Recycling Excavated Material £152 £90 £98 £340 Lone Worker Risk Management £113,894 £32,192 £56,715 £202,801 Multiple Cable Ratings in Ventilated Tunnels £14,407 £8,482 £9,296 £32,185 Advanced Harmonic Monitoring £25,420 £8,647 £19,794 £53,861 Total £3,339,528

7

8 Highlights

9 Online Condition Monitoring Technological breakthrough enables automated location of multiple incipient switchgear and cable defects.

Switchgear Partial Discharge (PD) in air insulated switchgear induces transient voltages that propagate rapidly over the switchgear metal panels. Due to the very high frequency of these pulses, the energy travels across the panel surface by the ‘skin effect’ and will easily move to panels adjacent to the one with the source of discharge activity. The problem becomes more complicated when there are multiple sources of PD as can be seen in Figure 1. Here there are two switchgear panels with PD and the activity can be seen across many channels. It is not possible to tell from magnitude alone which panels have the active sources.

Figure 1: PD Criticality at Site with Two Sources of Activity

In order to overcome this, ‘Precedence detection’ (technology based on a Field-Programmable Gate Array or FPGA) has been developed and introduced into the PD detection system. It can determine which detecting channel was first to ‘see’ a PD signal that is picked up by multiple channels. The discharges detected by channels that are not precedent, i.e. were not detected first, are then re- classified such that they do not contribute toward the criticality of that channel. In this way the panels that have the discharges are the only ones for which detected pulses are not re-classified and their criticality remains high as can be seen in Figure 2.

Figure 2: Same Site with Precedence Detection

The development of the precedence technology is significant as it improves the reliability of the overall system and provides high confidence that a remotely detected PD is genuine.

Figure 3 below shows the trend in the partial discharge activity detected on a panel neighbouring the panel with a discharge source before and after the introduction of Precedence technology. The red line shows activity classified as PD and the orange line shows activity that would have been classified as PD had it not been re-classified as a result of the precedence information.

Figure 3: Trend in PD activity on panel neighbouring the discharge source with and without precedence technology.

This shows the benefit of the re-classification process and the added clarity in interpretation of the monitoring data. It allows the defective asset to be identified remotely without the need for on-site testing.

10 Cable Online cable PD mapping (or online incipient fault location) is a relatively new technology and has so far been conducted over short periods of time due to the complexity of the test procedure. This has resulted in a number of drawbacks:  Only a small number of data points can be collected, reducing the accuracy of the testing.  PD activity in cables can vary significantly in magnitude and repetition rate over time, resulting in some defects being only active for a few hours a day.

Recent technical developments carried out as part of the online condition monitoring project has allowed this process to be automated, enabling the activity and for the first time, the location of incipient defects to be tracked over extended periods of time. A smart trigger unit connected to a single current transformer (figure 4) ensures that all discharging cable defects are detected.

Figure 4: High Frequency Current Transformer and Smart Trigger Unit

Figure 5 demonstrates the improved accuracy and more representative results that can be achieved using auto-mapping, compared to manual cable mapping. The 3D map can be built from thousands of data points captured over several days, reducing the probability of smaller PD sources not being detected. In this example, the same circuit was tested using both techniques and auto-mapping revealed two PD sources not detected whilst carrying out the manual mapping.

3 PD 1 PD Magnitude (pC) sources source detected detected

Time

Location (m) Manual Mapping Automated Mapping

Figure 5: Same Circuit Tested Using Manual and Automated Online Mapping

Conclusions As the cost of equipment decreases and the performance of PD detection systems improves, Online condition monitoring is expected to play an increasingly vital role in the management of network assets (In the short term for switchgear, and in the longer term, as the technology further matures, for the management of underground cables). The recent developments of automated mapping and precedence detection provide a robust platform for accurate and cost effective location of incipient defects.

11 Preparing For the Effects of Climate Change

The scientific evidence base for climate change is growing and requires the UK to respond in two different ways. Our first priority must be to change the way that we generate and use energy in order to structurally change the carbon footprint of our country, and its contribution to future climate change. Secondly, we need to understand what level of climate change has already become ‘unavoidable’ and what impacts a changing climate will have on our daily lives.

The first of these is often referred to as ‘Climate Change Mitigation’ and is one of the driving forces behind our R&D strategy. Climate Change Mitigation is the central reason we undertake work to understand Future Network Scenarios (see page 15). A future in which we generate and use energy in a very different way will require new approaches to our electricity infrastructure; it is important to widen our set of engineering and commercial solutions to providing new capacity, and to be able to apply the best possible solution to an issue, or achieve Optimal Network Design (see page 79).

The second of these challenges is referred to as ‘Climate Change Adaptation’. The Department for the Environment, Food and Rural Affairs (DEFRA) is tasked with assessing the readiness of the UK to cope with climate change. In order to carry out its assessment, it placed a legal duty on major infrastructure providers, such as UK Power Networks, to carry out a risk assessment of the impact which climate change may have on our business activities. DEFRA required a full report on both the anticipated impact and the actions which we are taking to address issues identified.

In common with the other Distribution Network Operators, UK Power Networks had been addressing the issue of Climate Change Adaptation since 2007. We have steadily built an R&D portfolio to investigate the issues, the early results of which were reported in our Climate Change Adaptation Report which will be available on the DEFRA website. A number of highlights of the work are shown below.

In particular the R&D portfolio gave us early familiarity with working with the Met Office’s climate change projections which were provided by the end of 2007 and showed an early sweep of areas in which climate change may impact our operations. It enabled us to provide firm comments on the potential for changes to extreme events such as lightning storms, snow and blizzard conditions and to understand the impact of higher ambient temperatures on current-carrying capacity of our cables and plant. Two ongoing projects are investigating the relationship between climate and vegetation growth close to our overhead lines and between climate and the effectiveness of soil to provide a good electrical earth terminal for our substations.

UK Power Networks was able to confirm to DEFRA that the issue of adapting to climate change is firmly on the management agenda, and that the majority of issues can be dealt with within our existing organisational and regulatory structure. We will work with the rest of the industry to agree updated standards for a new network construction, where a marginal increase in cost can increase our resilience to climate change and where the cost is reasonable when weighed against the uncertainty in future climate predictions.

Typical1m cable depths 0.5 ‐ Soil

Geology

Changes in temperature and rainfall may have an impact on soil properties, Changes in temperature, rainfall and soil conditions may and its ability to act as an effective earth terminal for our plant. The change the habitats for vegetation, shown shaded here red/amber/green shading indicates the difficulty in making an earth contact in (see page 50) current climate and soil conditions .

12 Aura NMS

UK Power Networks installed and commissioned an energy storage device at Hemsby, Norfolk as part of the Aura NMS IFI project which you can read about on page 56. Having commissioned the device, UK Power Networks is running a Low Carbon Network Fund project to gain real practical experience with the device and its possibilities. Below is one of the articles that appeared in the June 2011 edition of Transmission and Distribution World magazine.

This article was first published in Transmission and Distribution World magazine June 2011 Transmission and Distribution World Vol.63 No. 6

13 Early Learning through IFI Leads to Large Scale Trials

The Intelligent Distribution Network Monitoring IFI project carried out in 2008/2009 set out to investigate the viability of increased monitoring of the 11kV and LV networks, and to evaluate the cost-benefit case associated with the deployment of a specific monitoring technology, based on optical current sensors. Existing monitoring and control devices in the networks were taken into consideration and a high level model for the costs and benefits associated with different levels of monitoring was developed.

The project concluded that by using existing systems in novel ways, and targeted additional sensor installation it would have the potential to lead to more effective planning, better investment decisions, asset management and operational decisions.

It is widely acknowledged that a greater visibility of power flows on the distribution network will be required in order to manage the more complex load profiles and greater levels of distributed generation expected in future. The introduction of the LCNF and an internal programme to upgrade communications to all LPN secondary sites equipped with Remote Terminal Units (RTU) (RTUs are present at 45% of the population of secondary sites in LPN or 7,500 sites) provided an ideal opportunity to setup a large scale demonstration to highlight the business benefits of the smart collection, utilisation and visualisation of existing data (Potential visualisation shown on Figure 6).

Network view

Secondary substations view

Detailed view

Figure 6: Potential Visualisation Showing How Potential Problem Sites may be Highlighted (Red Dots) and How Information may be Displayed

The project will also deliver learning on the appropriate level, frequency and type of monitoring required by DNOs. Finally, the Distribution Network Visibility project will expand the trial of optical sensors for sites with no RTUs. These will include:  A novel three-phase optical sensor that can be used on three-phase HV cables.  An overhead sensor which is widely used by utilities in Denmark and Australia.

Figure 7: Overhead Line Optical Sensor

14 Individual Project Reports

15 Future Vision and Aspirations for the Network

Whilst all the projects and activities reported here need to meet the criteria laid out by Ofgem, the starting points for activities going forward are our aspirations as a network. UK Power Networks are proud to have a strong and consistent strategy leading the use of innovation across the business.

Aspirations

We believe that it is critically important to understand the quantitative risks posed by different Future Network Scenarios. Understanding the risks to the network from national and regional development plans for low carbon initiatives may make the case for early adoption of technology, leading to optimised investment in the network.

By forming an understanding of the new challenges to the network, we believe we can avoid the otherwise necessary but disproportionate network investment which would inevitably result from the various higher demands of heat pumps, electric vehicles and Distributed Generation (DG).

As a distribution network operator, the Smart Management of Assets is a core part of our business. The future aspiration for UK Power Networks is for a single source of detailed, complete and predictive asset data. By capturing the data available on asset installation, environment, load, load history, degradation modes and condition in one place, models of likely life can be improved. An input and an output of these models will be calibrated degradation models for the assets. These degradation models will help to predict future risk from a number of factors. By understanding and monitoring our network in a much more detailed way, network investment can be further optimised.

Visible Flexible Networks form the foundation of a smart grid, capable of handling higher and bi- directional flows. As such, this aspiration is aimed at achieving a modelled network whose state is known in real time. This would enable a network and its assets to be optimised whilst remaining within regulatory and security limits. This is a holistic vision bringing together Research and Development (R&D) outputs on asset life prediction, environment, network topology, customer loads and other factors. The flexibility and control is via more numerous remote control points, automation scripts, potentially more power factor correction, power flow management devices and complete control room visibility of the stability of the network. In the long term we expect informed control engineers to intervene more frequently or automatically flex the network to manage faults, peak loads and distributed energy resources. The initial benefits will come from dispatching the workforce more efficiently and less often.

As network operators we inevitably suffer faults on our networks. This is from a combination of cable strikes, vandalism, defective and aging assets, and the operation of the network. Full Fault Knowledge is therefore an aspiration that would improve the operating costs due to faster fault finding and repair, and at the same time reducing the pressures on our workforce.

The Optimal Network Operation aspiration focuses on projects that enable higher and potentially clustered new demands to be met economically, with new tools, technologies and processes. Operational best practices, improved processes, technologies, scenario information and load signals will enable our network to deliver more with less. An optimal network would in some cases turn connection requests to its advantage and use Demand Side Management (DSM) to manage constraints. Importantly, UK Power Networks’ environmental initiatives are a significant part of this aspiration. This is supported by the fact that improving our environmental performance often leads to business efficiencies at the same time.

16 Future Networks Scenarios

17 Future Networks Scenarios

Contents

Growth in City Centres...... 19 Bankside Heat Transfer ...... 21 Feasibility of an Active Network Management Solution (Closed) ...... 23 International DSM Survey (Closed)...... 25 High Performance Computing Technologies for Smart Distributed Network Operation (HiPerDNO)...... 27 Supergen 3 – HiDEF Highly Distributed Energy Futures ...... 29

18 Growth in City Centres

The Growth in City Centres project is aimed at evaluating innovative Description of Project ways of dealing with the increasing load demand in cities in a timely, efficient and cost effective manner.

Expenditure for EPN LPN SPN Financial Year External £0 £96,917 £0

Internal £0 £8,400 £0

Total £0 £105,317 £0

Costs allocated to London Power Network (LPN) as the project will have most applicability to this network.

External £235,802 Expenditure in Previous (IFI) Internal £23,357 Financial Years Total £259,159

Total Project Costs Projected 2011/12 External £15,000 (Collaborative + £ 382,439 costs for UK Power Internal £2,000 External + Networks Total £17,000 UK Power Networks)

 Power electronics. Technological Area  Technologies to increase power flows (DC Cables, and / or Issue superconducting cables, water cooling of cables in ducts, Addressed by Project dynamic cable ratings).

Project Project Residual Overall Project Benefits Type(s) of innovation Risk Score Radical Rating involved

9.6 3 6.6

The primary benefits associated with this project are expected to Expected Benefits of include an improved understanding of the techniques for increasing Project network capacity, performance, utilisation of space and operational resilience.

Expected Timescale Duration of benefit 2015 10 to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 25% Present Costs) x - Probability of Success

19 The areas investigated within this project touch on new devices or installations at a relatively early stage of development. Whilst one new product has been delivered (compact transformer), the cable Potential for Achieving solutions require further trialling and the power electronics aspects Expected Benefits would require both extensive product design and development and prototyping.

The project has made some progress towards identifying and developing the component parts of various solutions which could be taken forward into testing and field trials.

In the power electronics area, configurations and specifications have been investigated with key manufacturers for a device that could enable power flows on the 11kV system to be controlled between main substations to improve capacity and supply reliability.

The different scenarios in which the device would be used have been defined and the performance of the device has been simulated to demonstrate the potential for releasing existing transformer capacity in normal and contingency situations.

Substation space constraints have been identified as a key challenge Project Progress and further work would be required to better understand the space March 2011 and practical requirements of such a solution, including modular designs and the existence of suitable sites.

In the cables area, work has concentrated on investigating the high- level potential for increased ratings through distributed temperature sensors, DC cables, superconducting cables, water cooling of cables in ducts, and using other techniques such as installation of large diameter cables into ducts. Current superconducting cable technology was found to be underdeveloped for use in smaller ducts, although it was identified developing single-phase, warm dielectric superconducting cables for larger 4” ducts could be feasible.

All of the areas identified are systematically being reviewed for their potential and next steps which would be required.

Collaborative Partners PPA Energy, Schneider Electric

R&D Provider Imperial College, Strathclyde University, Southampton University

20 Bankside Heat Transfer

Substation transformers generate heat, particularly during peak loads. This heat is normally lost to the environment, often by energy- intensive forced cooling. The re-planted substation at Bankside, adjacent to the Tate Modern, has used transformers with water cooled heat exchangers. It is proposed that the waste heat from the Description of Project transformers will be used by the Tate Modern to assist with their space heating. This will benefit the Tate by providing low carbon heat. The benefits for UK Power Networks are that less energy will need to be expended within cooler fans at the substation, and lower maintenance and replacement cost will be incurred. The overall carbon footprint of the site and assets will be reduced.

Expenditure for EPN LPN SPN Financial Year External £0 £30,253 £0

Internal £0 £6,322 £0

Total £0 £36,575 £0

The costs have been allocated to LPN as the trial is being carried out at Bankside substation in London.

External £666,327 Expenditure in Previous (IFI) Internal £86,678 Financial Years Total £753,005

Total Project Costs Projected 2011/12 External £15,000 (Collaborative + £809,908 costs for UK Power Internal £5,000 External + Networks Total £20,000 UK Power Networks)

Technological area The oil to water heat exchangers at this scale and for this purpose are and / or issue novel, as is the specific heating arrangement. Addressed by Project

Project Project Residual Overall Project Benefits Type(s) of Innovation Risk Score Significant Rating Involved

4 1 3

Benefits are expected to include:  Heat used by a third party replacing a high CO2 heat source. Expected Benefits of  Fewer maintenance interventions for cooling. Project  Less energy expended for cooling via less auxiliary electricity consumption.  Lower noise level from coolers.

Expected Timescale Expected early Duration of benefit 20 Years to Adoption 2012 once achieved

21 Project NPV (Present Benefits – Probability of Success 75% Present Costs) x £200,000 Probability of Success

The water temperature is not as high as predicted, but there is Potential for Achieving potential to provide a benefit for a number of heat (or pre-heat) Expected Benefits applications.

The installation is able to provide hot water from the recovered heat. Project Progress The works at the Tate are not yet complete to enable heat to be March 2011 transferred. Some minor work is to be completed and some software updates are required.

Collaborative Partners Tate gallery

Wilson Transformers, R&D Provider Arup

22 Feasibility of an Active Network Management Solution (Closed)

Active Network Management (ANM) is concerned with facilitating increased access to existing or future networks. Through the implementation of ANM, more generation or demand can be connected to the network than according to the conventional planning approach. ANM manages the consumption or injection of power to operate the network within voltage and thermal constraints, should they occur on the network in real-time. Description of Project

The project is concerned with assessing the feasibility of extending the generation export from an existing CCGT by actively monitoring and managing access to the capacity available on the Norfolk 33kV network in real-time. At the present time, the CCGT is restricted to maximum output levels based on the seasonal ratings of the surrounding network.

Expenditure for EPN LPN SPN Financial Year External £17,800 £5,386 £11,813

Internal £1,653 £500 £1,097

Total £19,454 £5,886 £12,910

The costs have been allocated in proportion to the amount of connected distributed generation.

External £38,780 Expenditure in Previous (IFI) Internal £7,594 Financial Years Total £46,373

Total Project Costs Projected 2011/12 (Collaborative + £84,967 costs for UK Power Project closed External + Networks UK Power Networks)

Technological area Active Network Management solutions to increase installed generator and / or issue capacity and generator export on to the existing network and avoid Addressed by Project the need for network reinforcement.

Project Benefits Project Residual Overall Project Type(s) of Innovation Incremental Rating Risk Score Involved 14.4 -4 18.4

 Identifying the potential increase in CCGT energy production via the implementation of the ANM scheme.  The ANM scheme can be considered to represent a smart grid platform that can be added to as further generation or load Expected Benefits of connects to the network and as a basis for resolving voltage Project constraints on the network.  Proving the technical and economic aspects of ANM will permit UK Power Networks to facilitate more connections to existing networks, avoiding expensive network reinforcement, where it makes economic and carbon sense.

23 Expected Timescale Duration of benefit Year 2010 10 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 75% Present Costs) x £300,000 Probability of Success

The technical specification provided by the project outlines at a high- level the components and architecture of the proposed ANM deployment.

Potential for Achieving The ANM scheme being considered in this project could be Expected Benefits implemented elsewhere for new or existing generator connections to constrained networks. Providing a long-term or intermediate solution prior to reinforcing the network. This is particularly relevant to the connection of intermittent renewable energy sources such as wind farms.

The feasibility study stage of the project was completed with the submission of the final technical specification by Smarter Grid Solutions. The project found that the deployment of ANM could enable significant additional energy production by the CCGT unit. Such an ANM scheme could be extended to include other generators in the area, including new wind farms. A follow on trial is being considered as part of a potential Low Carbon Networks Fund project.

A ‘principles of access’ workshop facilitated by Smarter Grid Solutions discussed the rules that govern how more than one generator is approached for curtailment, i.e. should all generation be curtailed at the same time by a proportional amount, according to last in first off Project Progress (identified as the most suitable in the existing regulatory environment) March 2011 or based on the carbon production associated with the generator. Many other options exist and this project raised the profile of these issues within UK Power Networks. The output of the workshop has been used to inform the way constrained connections could be offered to DG developers. It is envisaged that it will be technically and commercially feasible to facilitate the connection of additional generation to the existing network.

In trials of this type the DG operator or developer must want to proceed with the demonstration. Similar ANM solutions by Smarter Grid Solutions are being deployed as part of the Low Carbon London project and form part of our flexible plug and play submission.

Collaborative Partners n/a

R&D Provider Smarter Grid Solutions

24 International DSM Survey (Closed)

KEMA worked with UK Power Networks to investigate the opportunities that might exist for distribution networks via active customer engagement in demand management. Sample customer trends were analysed in order to understand the extent to which on-site demand can be mitigated during peak periods. Investigated further was the mix of services (essential and Description of Project otherwise) employed within each of the premises and how mitigation strategies would work with each of the services.

The project has been further informed by an international investigation of demand side options, where the most prominent (and likely to be the most appropriate) options have been considered in the context of the project itself.

Expenditure for Financial EPN LPN SPN Year External £14,505 £9,270 £9,276

Internal £1,355 £866 £867

Total £15,860 £10,136 £10,142

The costs have been allocated in proportion to the amount of connected customers.

External £28,200 Expenditure in Previous (IFI) Financial Years Internal £7,594

Total £35,794

Total Project Costs (Collaborative + External Projected 2011/12 costs £72,256 Project closed + for UK Power Networks UK Power Networks)

Technologies considered were: Technological area and /  Wireless interruption of air conditioning plant. or issue Addressed by  Demand side use of standby generation. Project  Incentivised turn down options.  Building management innovation.

Overall Project Benefits Project Residual Type(s) of Innovation Project Significant Rating Risk Involved Score

7.6 4 3.6

Benefits are expected to include:  Network peak demand reduction. Expected Benefits of  Technology replication (elsewhere on wider network). Project  Understanding of the potential for reduction in network reinforcement.

Expected Timescale to Duration of benefit once Year 2012 10-20 Years Adoption achieved

25 Project NPV (Present Small within the Probability of Success 50% Benefits – Present Costs) area of x Probability of Success investigation

There is likely to be higher potential to realise benefit outside of Potential for Achieving the area of investigation i.e. elsewhere on the network working Expected Benefits with less complex customer configurations.

The project started in January 2010 and was concluded in September 2010. A report on the value and options of DSM as a distribution networks management tool was produced by KEMA. Project Progress March 2011 The work was a key input to UK Power Networks’ scoping of the Low Carbon London project which is currently underway with funding allocated from the Low Carbon Network Fund (Tier 2) in 2010.

Collaborative Partners n/a

R&D Provider KEMA

26 High Performance Computing Technologies for Smart Distributed Network Operation (HiPerDNO)

The mass deployment of network equipment sensors and instrumentation, millions of smart meters, small-scale embedded generation, and responsive load will generate vast amounts of data which potentially could be analysed in real-time to identify trends or incipient faults. So-called cloud and grid computing could enable scalable data mining, feature extraction, and near to real-time state estimation. These and other High Performance Computing (HPC) tools and techniques have been recently developed to cost-effectively Description of Project solve large scale computational challenges in areas such as genomics, biomedicine, particle physics and other major scientific and engineering fields that require similarly scalable communications, computation and data analysis.

HiPerDNO is European Commission funded FP7 ICT Energy STREP (Specific Targeted Research Projects) project which plans to develop solutions to address future electricity distribution networks.

Expenditure for EPN LPN SPN Financial Year External £121 £77 £77

Internal £1,110 £709 £710

Total £1,231 £787 £787

The costs have been allocated in proportion to the number of customers connected to each licence area.

External £0 Expenditure in Previous (IFI) Internal £7,594 Financial Years Total £7,594

Total Project Costs Projected 2011/12 External £0 (Collaborative + costs for €6,500,000 Internal £10,000 External + UK Power Total £10,000 UK Power Networks) Networks

 Development and testing of novel high performance computing information and communications technology for active distribution networks.  Development and test of data mining features that extract relevant information.  Development and testing of a high-speed messaging layer.  Calculation and utilisation of a typical measurement data set for Technological area large amount of smart meter data in future low and medium and / or issue voltage networks. Addressed by Project  Customer integration in active network operation.  Development and testing of a real-time distribution state estimator.  Identification and analysis of new generation DMS functionalities.  Development and test of a new generation network service restoration algorithm.  Development of novel state estimation algorithms for distribution networks.

27 Project Benefits Project Residual Overall Project Type(s) of Innovation Incremental Rating Risk Score Involved 8.6 -1 9.6

This research project will develop a new generation of distribution network management systems that will exploit novel near to real-time HPC solutions. The solutions are expected to have inherent security and intelligent communications for smart distribution network Expected Benefits of operation and management. Cost effective scalable HPC solutions Project will be developed and initially demonstrated for realistic distribution network data traffic and management scenarios. The demonstrations will be via off-line field trials involving several distribution network owners and operators.

Expected Timescale Duration of benefit Year 2015 10 Years to Adoption once achieved

This project is expected Project NPV to deliver benefits in the (Present Benefits – order of millions of Probability of Success 75% Present Costs) x pounds. As part of the Probability of project the real value will Success be calculated.

The project is currently proceeding as planned and successfully completed the first annual external review in February 2011. At Potential for Achieving present no issues or problems are envisaged for the remainder of the Expected Benefits project and therefore the project has very good potential to achieve the expected benefits.

The outcome of the external review confirmed that good progress was being made and that the project has achieved most of its objectives Project Progress and technical goals for the period with relatively minor deviations. All March 2011 deliverables for year 1 have now been accepted by the reviewers and the EC project officers.

HiPerDNO is an Integrated Project is supported by the European Collaborative Partners Commission under the 7th framework programme. www.hiperdno.eu

Brunel University IBM Haifa Electricité de France Indra R&D Provider Elektro Gorenjska (Slovenia) Korona Fraunhofer- IWES Union Fenosa Group GTD Spain University of Oxford

28 Supergen 3 – HiDEF Highly Distributed Energy Futures

The HiDEF programme, funded by the EPSRC, researches the essential elements of a decentralised system that could be implemented over the period 2025 and 2050 to enable all end users Description of Project to participate in system operation and real time energy markets. It has been structured to support the evidence base relating to key questions of current concern within industrialists, Ofgem and DECC.

Expenditure for EPN LPN SPN Financial Year External £9,216 £5,890 £5,894

Internal £916 £585 £585

Total £10,132 £6,475 £6,479

The costs will be allocated in proportion to the number of customers in each licensed network.

Expenditure in Previous (IFI) New Project 2010/2011. Financial Years

Total Project Costs Projected 2011/12 External £20,000 (Collaborative + costs for £ 4,500,000 Internal £3,000 External + UK Power Total £23,000 UK Power Networks) Networks

The HiDEF programme has five workstreams which will address the Technological Area issue described by its name. The workstreams are Decentralised and / or Issue Energy, Decentralised Control, Decentralised Network Infrastructure, Addressed by Project Decentralised Participation and Decentralised Policy and Macro Impact Assessment.

Project Project Residual Overall Project Type(s) of Innovation Residual Risk Risk Score Radical Involved 7.2 -2 9.2

The Decentralised Energy workstream will provide a quantified understanding of DER and their performance. This will be in the form of models of single units, cells and multiple cells to assess thermodynamic analysis, life cycle assessment and environmental cost benefit analysis. The work stream will identify the energy and carbon implications of technology options.

The Decentralised Control workstream will develop control solutions for single units, cells and multiple cells. The workstream will Expected Benefits of investigate the behaviour of populations of multiple small generators. Project It will concentrate on security and resilience of communications and Control systems.

The Decentralised Network Infrastructure workstream will develop MV/LV architectures and tools to guide investment to support future decentralised network operation. Planning tools to take into consideration DER characteristics, potential, uncertainty and optimisation.

29

The Decentralised Participation workstream will research the components essential to the realisation of a distributed market place. This workstream will design a market place, investigate market based response, trading contracts and products.

The Decentralised Policy and Macro Impact Assessment workstream will conduct a review of current mechanisms of policy delivery in the UK, compare market structures and examine the potential for alignment with various market aggregations.

The whole consortium will hold six monthly workshops to consider the results of the work streams to inform debates that are current in the industry.

Expected Timescale Duration of benefit Year 2012 onwards 20 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 25% Present Costs) x £2,000,000 Probability of Success

The HiDEF research programme has progressed and a number of valuable device and system models, analysis tools and laboratory prototypes and rigs have now been realised. These will support the quantitative appraisal of the performance of critical elements of a highly distributed energy system. HiDEF researchers are furthermore engaging in a number of ‘impact case studies’ through which they are providing support and analysis to existing demonstration projects and DER deployments (including local concentrations of roof-mounted PV installations). These include community groups (e.g. Blacon), and local government (e.g. Dumfries & Galloway Council) as well as the partnering network operators.

The Decentralised Energy Workstream has created detailed models of characteristic dwellings (pre and post 2016 building regulations), and these have been used to generate high resolution stochastic models of energy and heat demands of significant populations. Initial studies with these have indicated that a flexibility of up to two hours in Potential for Achieving the operation of electrical heating can be adequately accommodated. Expected Benefits Further work is currently quantifying the potential for peak shaving.

A number of new cell control solutions for demand and generator management have been introduced by the Decentralised Control Workstream team, and are being tested on network studies and on real time simulation platforms. The impact of these on network performance and system stability are now being appraised. Furthermore, improved power electronic interfaces for PV systems have been rig-tested and are displaying improved power quality credentials.

Work continues in the Decentralised Network Infrastructure Workstream, which now includes a network planning tool extended to include the optimal integration of electric vehicles as responsive demand and dispatchable storage.

30 The PhD researchers within the Decentralised Participation Workstream continue to progress enhanced trading strategies utilising a VPP framework to include demand response, and an advanced agent-mediated participation scheme through which demand flexibility can be more fully (and fairly) utilised. The demand side elasticity analysis is now being supported by data from the California state pilot project.

The economic implications of the highly distributed system continue to be appraised by the Decentralised Policy and Macro Impact Assessment team. An interregional analysis of the economic and environmental impact of CHP within urban environments has been completed, with particular focus to date on the economies of Glasgow and Scotland. A new computable general equilibrium model of Scotland is furthermore providing for the identification of macroeconomic impacts of technology options and recognition of their policy implications.

The project team is now almost up to its full complement, and good progress is being made across the workstreams. Simulation tools, models and laboratory rigs have been created, and these are now being used by the researchers to analyse and test the proposed schemes for accommodating and utilising highly distributed resources. Progress has been reported at project management meetings, and disseminated at international conferences (most recently for example at CIRED). The six monthly workshops continue, Project Progress with April seeing the consortium host the Microgen’11 international March 2011 conference in collaboration with IEA Annex 52. One hundred and fifty delegates from around the world benefited from the exchange of experience in technology development and microgeneration deployment shared by industrialists, utility partners, technology developers, and researchers. The project consortium has been further expanded with the addition of Community Energy Scotland, and this is now providing a valuable insight into the aspirations and challenges faced by community groups in relation to distributed energy.

EPSRC and the following industrialists: Community Energy Scotland Delta Energy & Environment Intelligent Power Systems Collaborative Partners National Grid Western Power Distribution ScottishPower Energy Networks Scottish and Southern Energy

University of Strathclyde supported by: University of Bath Cardiff University R&D Provider University of Oxford Loughborough University Imperial College London

31

32 Smart Management of Assets

33 Smart Management of Assets

Contents

Online Condition Monitoring...... 35 Advanced Management of Tap Changers ...... 38 Intelligent Condition Monitoring and Diagnosis ...... 40 Understanding Aging Mechanisms in XLPE cables ...... 43 Condition Monitoring of Composite Insulators (closed)...... 45 Grid Transformer Monitoring...... 47 Supergen V – AMPerES (closed)...... 49 Power Networks Research Academy...... 51 Vegetation Management...... 54 Tree Growth Regulator ...... 56 GIS Data Definition ...... 58 Transformer Oil Health Index Tool (closed) ...... 60

34 Online Condition Monitoring

The use of partial discharge measurement is a well known method Description of Project of checking the condition of electrical insulation. Over the past 10 years, UK Power Networks has been actively involved in the development of online partial discharge monitoring and mapping techniques. Opportunities to improve the existing technology have been identified. This project has taken the laboratory into the distribution network to monitor underground cables and switchgear.

EPN LPN SPN Expenditure for Financial Year External £27,375 £282,877 £146,001

Internal £2,297 £23,736 £12,251

Total £29,672 £306,612 £158,252

The costs have been allocated in proportion to length of installed HV cable that is directly earthed.

External £3,080,793 Expenditure in Previous (IFI) Financial Years Internal £268,085

Total £3,348,878

Total Project Costs Projected External £22,000 (Collaborative + 2011/12 Costs £3,874,973 Internal £5,000 External + for UK Power Total £27,000 UK Power Networks) Networks

The issues being investigated by the project are: Technological Area  Online fault detection and location. and/or Issue Addressed  Pre-emptive fault repairs. by Project  Cable replacement and maintenance strategy.  Quality of supply improvement.

Overall Project Benefits Project Residual Project Type(s) of Innovation Rating Risk Significant Score Involved 17 -2 19

Benefits are expected to include:  The ability to target the replacement of cable. Expected Benefits of  The ability to identify faults (cable and switchgear) before they Project occur, carryout repairs and reduce the number of customer interruptions.  Improved asset management.

Duration of Expected Timescale to 2011 Benefit Once 20 years Adoption Achieved

35 Project NPV (Present Benefits – Probability of Success 75% £4,800,000 Present Costs) x Probability of Success

The level of benefits delivered is steadily increasing as a growing number of preventive repairs are being carried out, a number of Potential for Achieving equipment have been purchased outside of the Innovation Funding Expected Benefits Incentive scheme and UK Power Networks is currently evaluating several possible deployment scenarios.

Progress: Following a number of years of intensive development, the past year has concentrated on the following activities:

 Reduction of maintenance cost for the system on-line monitoring system: Various improvements have enabled to reduce the future expected maintenance cost per monitoring equipment by 25%.  Precedence technology evaluation: Precedence technology has been retro-fitted to 10 sites with ASM PD monitors . It confirmed the benefit of the precendence technology by rejecting non genuine PD indications.

Benefits of the Precedence Technology Project Progress March 2011  Automated cable mapping has been carried out on several cable circuits, demonstrating the benefit of this tool to detect and locate incipient cable defects.

3 PD

Magnitude (pC) sources detected

Time

Location (m)

Auto-mapping Results Showing Three Incipient Cable Defects

36  On-line mapping field trials:  PD mapping was carried out on 30 cable circuits and of these a defect location was found on 20 (66%).  11 PD surveys were carried out on switchgear panels resulting in 6 PD site identifications.  18 requests for preventive maintenance actions were compiled and sent to relevant UK Power Networks department (e.g. distribution planning, Network Operations, Asset management). A number of replacement schemes are currently in progress.

Business deployment: The integration of the technology into Asset Management processes is being finalised and the following applications are being considered:

 Management of high risk switchgear: The online partial discharge technology can be used to:  Detection of defects on monitored sites.  Extend the life /defer the replacement of switchgear panels  Monitor high risk sites.  Management of HV cable problems (e.g. multiple faults): Cable circuits can be assessed and monitored following repeat HV underground cable faults.  Target cable replacements: The web based analysis interface enables cable circuits affected by incipient faults to be prioritised for subsequent field investigation and testing.  Safety: The online monitoring equipment can be setup so that an audible alarm sounds if partial discharge exceeds a defined threshold. After an early review by Asset Management widespread roll-out on cables is unlikely to occur. Conference Publications The following two papers were published and presented at the CIRED 2011 conference:  Improving the management of MV underground cable circuits using automated online cable partial discharge mapping  The location of switchgear partial discharge by panel and techniques to correlate switchgear and cable partial discharge with load and substation environment.

Collaborative Partners IPEC Ltd, EPSRC

IPEC Ltd, PPA Energy, HVPD, Southampton University, Cobham R&D Providers Technical Services, Glasgow Caledonian University, University of Strathclyde

37 Advanced Management of Tap Changers

This project is assessing various methods of analysing the Description of Project performance and duty of tap changers, both in service and at maintenance interventions.

Expenditure for EPN LPN SPN Financial Year External £87,086 £36,407 £48,084

Internal £7,415 £3,100 £4,094

Total £94,501 £39,506 £52,178

The costs have been allocated in proportion to the number of primary transformers supplying the distribution network.

External £84,660 Expenditure in Previous (IFI) Internal £7,594 Financial Years Total £92,254

Total Project Costs Projected 2011/12 External £0 (Collaborative + £280,149 costs for UK Power Internal £0 External + Networks Total £0 UK Power Networks)

Technological area Optimal asset management and maintenance of tap changers. and / or issue

Addressed by Project

Project Project Residual Overall Project Benefits Type(s) of Innovation Risk Score Incremental Rating Involved

13.6 -2 15.6

Expected benefits include:  Identification of tap changers that are not performing well in Expected Benefits of service. Project  Evaluation of methods for assessment of tap changer performance during plant outage and after maintenance interventions.

Expected Timescale Duration of benefit 2012 40 years to Adoption once achieved

Project has a small Project NPV negative NPV. Benefits (Present Benefits – are largely through Probability of Success 75% Present Costs) x safety improvements Probability of and improved knowledge Success of asset health.

38 One system has shown potential for providing reliable and flexible Potential for Achieving monitoring of tap changers. Some challenges remain before benefits Expected Benefits could be realised with other solutions.

Training has been provided for the offline acoustic and electrical parameter maintenance testers and necessary software upgrades completed. Further trials are awaiting an appropriate outage. These testers require some experience and history of interpreted tap- changer signatures and methods for developing this need to be explored further.

Six remote monitoring systems have been commissioned and are Project Progress functioning well. Reliable communications has been an issue in some March 2011 instances, which has identified a need for further work in this area. Additional work is also needed in order to maximise value from the data, including automatic interpretation and presentation in a user- friendly and meaningful way alongside existing tools and processes.

An acoustic method offered by BT using a fibre-optic system has not been pursued further because it was concluded that development of the technology was too immature and the high installation costs were not expected to be economically viable.

Collaborative Partners n/a

R&D Provider Dynamic Ratings, Inc., KBK Power Solutions, Zensol, BT

39 Intelligent Condition Monitoring and Diagnosis

The main objective of this project will be the development of a single Description of Project online condition monitoring system enabling:  Large amounts of network data to be remotely collected and processed.  Information relating to all the major electrical assets to be extracted (condition, residual life, safety hazards, etc.).  Key information to be dispatched to relevant business systems or staff.  Optimum use of data already available (SCADA, etc).

EPN LPN SPN Expenditure for Financial Year External £46,874 £15,945 £36,501

Internal £4,059 £1,381 £3,160

Total £50,933 £17,326 £39,661

The costs have been allocated in proportion to the number of primary substations.

External £41,780 Expenditure in Previous (IFI) Financial Years Internal £7,594

Total £49,374

Total Project Costs Projected 2011/12 External £0 (Collaborative + External £158,280 Costs for UK Power Internal £0 + Networks Total £0 UK Power Networks)

Technological Area and/or Issue Addressed Monitoring and management of major asset classes by Project

Project Project Overall Project Type(s) of Innovation Incremental Benefits Rating Residual Risk Score Involved Innovation 19.4 0 19.4

This project is expected to result in an operational expenditure Expected Benefits of reduction, deferment of capital expenditure, improved asset Project management, improved safety and the ability to demonstrate competent asset governance and risk management.

Expected Timescale to Duration of Benefit 2015 10 Years Adoption Once Achieved

Project NPV (Present Benefits – Probability of Success 75% Present Costs) x £2,900,000 Probability of Success

40 Work to date has illustrated that there are viable and cost-effective solutions to remotely capture, process, and automatically evaluate input data and present it to end-users in a clear and concise manner Potential for Achieving through a user-friendly interface. Expected Benefits The proposed solution could enable more efficient decision making based on accurate real time data which in turn will reduce operational and better target capital expenditure. It could also automatically deliver up-to-date asset performance (KPIs) and output measures.

Following on from the previous year’s work activities, a functional specification for an integrated intelligent condition monitoring and diagnostic business system has been produced.

After determining the principal internal and external business drivers (e.g. Quality of Supply performance; operational, safety and environmental events; etc.) four strategic subject areas were identified and evaluated as follows:  Understanding and specifying the basic Asset Data characteristics (i.e. 40 key asset categories; their failure mechanisms and symptoms of failure; detection and measurement; condition monitoring requirements; and input data specification).  Identifying and evaluating Network Risk (i.e. typical and catastrophic failure rates; interruption, environmental and operational risk; individual asset and population risk, asset ranking and prioritisation).  Designing a suitable Business System Framework (i.e. business system functionality; data capture and validation; data processing and storage; data warehouse, tools and applications; and end user warehouse).  Applying appropriate Intelligence and diagnostic techniques Project Progress (i.e. data analysis and evaluation; intelligent diagnostics, March 2011 knowledge library; asset health and performance; end-user and output requirements; and presentation, reports and alerts).

This analysis and evaluation carried out in the four subject areas led to the concept of an asset condition assessment matrix and the recommendation to work towards a proposed business system model where a number of existing and new IT systems are connected to a central data warehouse (based on OSIsoft PI) via an enterprise bus utilising a common information platform.

Work has also been undertaken in respect to identifying and evaluating suitable software applications for analytical, diagnostic and end-user interface purposes.

On-going Activities A number of options are currently under consideration. Some of the key aspects and tasks include:  Determine condition monitoring and supporting information data inputs and sources  Determine outputs and end-user requirements  Design and produce final specification for IT infrastructure  Start the detailed modelling and requirements specification, estimate data volumes  Formulate and implement field trials with pilot condition

41 monitoring solutions  Develop implementation plan  Review and validate selected path and partners

Collaborative Partners n/a

R&D Providers PPA Energy, IBM

42 Understanding Aging Mechanisms in XLPE cables

This project studies the performance of the materials used for cable The main objective of this project was to quantify and to model water uptake across the polyethylene or polyvinylchloride outer sheath of Description of project cables, as a function of time and service conditions. The project aimed to establish life expectancies of different cable sheath combinations. EPN LPN SPN External £17,389 £7,819 £9,792 Expenditure for Internal £1,615 £726 £909 financial year Total £19,004 £8,545 £10,702 The costs have been allocated in proportion to EHV underground cable. External £60,000 Expenditure in previous (IFI) financial Internal £11,759 years Total £71,759

Total Project Costs Projected 2011/12 External £0 (Collaborative + £390,000 costs for UK Power Internal £0 external + Networks Total £0 UK Power Networks)

Current IEC cable standards do not have a long term corrosion tests, because there is no scientifically proven evidence suggesting a Technological area problem exists. This project addresses the issue and will recommend and / or issue management policies and influence cable specifications. addressed by project UK Power Networks is particularly interested in keeping water out of cables for as long as possible because some UK design cables have a copper wire / aluminium foil screen combination. Project Project Residual Overall Project Benefits Type(s) of innovation Risk Score Radical Rating involved 10.6 -2 12.6 Benefits are expected to include: Improvement of security/quality of supply and a better understanding Expected Benefits of of the failure mechanism. Project Better planning of investments for the replacement of 132kV and 66kV cables.

Expected Timescale Duration of benefit Year 2012 50 years to adoption once achieved

Project NPV (Present Probability of Success 75% Benefits – Present £200,000 Costs) x Probability of Success The project is progressing according to plan. That means the following was completed : - the identification of material industrial formula, - the characterization of the sheath: thermo oxidation and its kinetic Potential for achieving values, expected benefits - the identification of each antioxidant and their impact on the polyethylene ageing, - the identification and the consequences of the plasticizer loss on the polyvinylchloride ageing.

43 Up to now the main results are as follows : Industrial formulations used in the essays have been identified and quantified. Some kinetic parameters have been defined following the accelerated ageing of pure polyethylene. These kinetic parameters characterize thermo-oxidation of the polyethylene and they will be implemented in the numerical model in progress. Each antioxidant impact has been identified following the accelerated Project Progress ageing of stabilized polyethylene. March 2011 Phenomena which control the antioxidant loss in the PE have been identified. Kinetic parameters which control the loss of the antioxidants in the PE have been specified.

All these results will be integrated in the ageing model in order to be able to quantify the water uptake across the outer sheath of the cable in function of time and service conditions. Collaborative Partners The French TSO and DNO (that is RTE and eRDF)

R&D Provider ENSAM Paris, EDF R&D

44 Condition Monitoring of Composite Insulators (Closed)

Composite insulators are now deployed throughout the world and are steadily replacing traditional ceramic and glass insulators. Low weight and physical robustness are two properties which have led to an increasing market share for composite insulators over the last 20 years. However, there is concern over the long-term ageing of these insulators. Description of Project

This work has characterised the millimetre scale arcing activity between water droplets and developed an experimental knowledge and theoretical understanding of how this leads to macroscopic behaviour. In particular, it identified the local surface conditions on the millimetre scale which cause the ageing of hydrophobic material surfaces.

Expenditure for EPN LPN SPN Financial Year External £26,317 £0 £7,661

Internal £2,452 £0 £714

Total £28,769 £0 £8,374

The costs have been allocated in proportion to the length of HV overhead line.

External £74,940 Expenditure in Previous (IFI) Internal £31,893 Financial Years Total £106,833

Total Project Costs Projected 2011/12 (Collaborative + costs for £144,310 Project closed External + UK Power UK Power Networks) Networks

Technological Area Develop reliability models for hydrophobic insulators, recommend test and / or Issue schedules for type approval and product development and identify Addressed by Project condition monitoring techniques for existing installations.

Project Benefits Project Residual Overall Project Type(s) of Innovation Significant Rating Risk Score Involved 10.4 3 7.4

The expected benefits included:  An improved understanding of insulation ageing.  A better understanding of risk associated with ageing insulation.  Reduced operational costs through extended times between Expected Benefits of insulator replacement. Project  Reduced outages as a result of reduced, unforeseen insulation failure.  Improved methods for testing of new products  Stronger management of suppliers.

Expected Timescale Duration of benefit Year 2011 20 Years to Adoption once achieved

45 Project NPV (Present Benefits – Probability of Success 25% Present Costs) x £ 100,000 Probability of Success

Potential for Achieving This project is now closed. Expected Benefits

The project was completed in February 2011.

Seven conference papers have arisen from this work and a number of Journal papers will be written in consultation with UK Power Networks staff.

The project has delivered a review of asset management tools and techniques for overhead line insulators. A clear structure for future management has been provided. This has included a model in which the state of insulator sets can be described in one of only four defined states. This enables management to consider transition between states as the key processes.

Most previously published work had been on transmission insulators. To understand and extend that work to distribution assets, two activities have been completed. Firstly a detailed analysis of some typical insulators taken from UK Power Networks has been completed. This has included electrical, physical and chemical characterisation. Issues of biofilms, UV radiation and non-rotational symmetry have been highlighted. In addition, the new method of measuring the whole insulator as a classical insulation material has proved uniquely successful in differentiating new and old samples.

Project Progress The second activity (to enable interpretation of published work to March 2011 distribution insulators) was to consider the microscopic discharge activity behaviour of discharges on surfaces, including the impact of surfaces and water droplets. This has been very successful and enabled a clearer understanding of issues of surface roughness, hydrophobicity and wetting behaviour.

Figure 8. High Speed Camera Images/Videos Synchronized with the Voltage and Leakage Current Signals

Collaborative Partners n/a

R&D Provider University of Manchester

46

Grid Transformer Monitoring

This project is evaluating the benefits of deploying Intellix MO150 transformer monitoring systems onto large power transformers.

Description of Project Two devices are installed on four typical grid transformers at two sites. Full installation involves the integration of alarms and monitoring data with existing UK Power Network’s SCADA and historic data acquisition into databases for strategic analysis.

Expenditure for EPN LPN SPN Financial Year External £8,475 £3,543 £4,680

Internal £2,252 £941 £1,243

Total £10,727 £4,484 £5,923

The costs have been allocated in proportion to the number of primary transformers supplying the distribution network.

External £131,119 Expenditure in Previous (IFI) Internal £22,104 Financial Years Total £153,223

Total Project Costs Projected 2011/12 External £0 (Collaborative + £174,542 costs for UK Power Internal £0 External + Networks Total £0 UK Power Networks)

Technological Area A range of grid transformer monitoring points, including cooler and / or Issue temperature, number of tap operations and dissolved gas analysis. Addressed by Project

Project Benefits Project Residual Overall Project Type(s) of Innovation Incremental Rating Risk Score Involved 10.4 -2 12.4

Expected benefits include:  Experience and assessment of a particular transformer monitoring solution. Expected Benefits of  Optimisation of power transformer monitoring and lifespan. Project  Reduction in risk of failure or uncontrolled ageing through real- time performance monitoring.  Gain experience in the use of real-time monitoring data to permit short-term overloading.

Expected Timescale Duration of benefit 2012 20 Years to Adoption once achieved

Project NPV NPV is slightly negative. Probability of Success 30% (Present Benefits – Main benefits are safety Present Costs) x related and improved

47 Probability of knowledge of asset Success health.

The solution is unlikely to be appropriate for a large proportion of the Potential for Achieving transformer population, but has the potential to be a tool for Expected Benefits monitoring a limited number of critical sites or problem installations.

There have been continued hardware failures of the Intellix units that have raised reliability concerns over these monitoring solutions.

A key learning point has also been the criticality of reliable and robust communications for monitoring solutions to be effective, and further Project Progress work on this area is now being explored. When units have been March 2011 operating as expected, communications drop-outs have reduced the completeness and value of historical data collected.

The field experience gained and capabilities of these monitoring solutions is currently under evaluation against a number of other monitoring solutions and devices.

Collaborative Partners n/a

R&D Provider GE Energy, MW Test Equipment Ltd, Drallim Ltd

48 Supergen V – AMPerES (closed)

Supergen was an EPSRC strategic partnership programme incorporating a collection of projects across a number of UK academic Description of Project establishments. This fifth call, Supergen V was titled Asset Management & Performance of Energy Systems (AMPerES).

Expenditure for EPN LPN SPN Financial Year External £0 £0 £0

Internal £149 £95 £95

Total £149 £95 £95

The costs have been allocated in proportion to the number of connected customers.

External £75,000 Expenditure in Previous (IFI) Internal £8,166 Financial Years Total £83,166

Total Project Costs Projected 2011/12 (Collaborative + £ 2,800,000 costs for Project closed External + UK Power Networks UK Power Networks)

The programme was split into 6 work packages, all of which were relevant to UK Power Networks:  WP 1 – Programme delivery, outreach and implementation. Technological Area  WP 2 – Enhanced network performance and planning. and / or Issue  WP 3 – Adaptable protection and control techniques. Addressed by Project  WP 4 – Infrastructure for reducing environmental impact.  WP 5 – Ageing mechanisms.  WP 6 – Condition monitoring techniques.

Project Benefits Project Residual Overall Project Type(s) of Innovation Radical Rating Risk Score Involved 11 -4 15

The expected benefits of this project were:  To deliver a suite of intelligent diagnostic tools for plant.  To provide platform technologies for integrated network planning Expected Benefits of and asset management. Project  To progress plans to develop and implement improved and reduced environmental impact networks.  To develop models and recommendations for network operation and management.

Expected Timescale Duration of benefit Year 2013 20 Years to Adoption once achieved

49 Probability of Success 25% Project NPV £150,000

Potential for Achieving Expected Benefits This project is now closed.

The project was completed in September 2010.

Topics where the impact of the research is judged to have been most significant are:  Condition monitoring.  Network placing models with different, new energy processes to optimise.  New fundamental research on power lines. Materials ageing research.

Outputs: There have been over 200 publications as a result of this work of which over 70 have been in Journals and 140 in conferences. All publications and reports are available to all the partners from a secure website: http://www.supergen-amperes.org/.

A number of demonstrator projects were also carried out, they included:  The detection, control and protection synchronous islands were demonstrated on a 50kVA diesel generator installed outside the laboratory at Queen’s University. The demonstration employed a real-time phasor measurement system. Project Progress  Optimised design of existing overhead lines was demonstrated by March 2011 Manchester through analysis of a ScottishPower wood pole line, and a National Grid lattice line.  A unique installation for transformer monitoring at National Grid comprising of two 275/132kV, 180MVA transformers. It was lead by Strathclyde who implemented results of research on condition monitoring architectures, diagnostics and machine learning.  Southampton, Strathclyde and Liverpool applied knowledge gained on partial discharge in cables to attempt to enhance UK Power Networks cable monitoring systems.

Follow up: Several reviews to identify follow up projects were held. The last at Manchester early 2011 identified three potential follow up collaborative projects (the lead academic is identified in brackets): Managing Continuity of Supply (Peter Crossley / John Morrow), Asset Management and Prognostics (Stephen McArthur), Improvement of Power Flow through Existing Assets (Konstantinos Kopsidas / Steve Swingler).

Many of the longer term research issues will continue to be addressed by the EPSRC sponsored Networks Hub Project and the two Grand Challenge project recently announced.

National Grid, ScottishPower Energy Networks, Scottish and Southern Collaborative Partners Energy, Energy North West, Western Power Distribution, CE Electric UK, NIE, Advantica

Universities of Manchester, Southampton, Edinburgh, Liverpool, R&D Provider Strathclyde, Queens (Belfast)

50 Power Networks Research Academy

The Power Networks Research Academy (PNRA) has been established through a strategic partnership agreement between the Engineering and Physical Sciences Research Council (EPSRC), electricity transmission and distribution companies, related Description of Project manufacturers and consultants. The Academy funds and supports PhD researchers in power industry related projects and help maintain and improve the research and teaching capacity in power engineering subjects.

Expenditure for EPN LPN SPN Financial Year External £39,565 £25,284 £25,301

Internal £4,295 £2,745 £2,747

Total £43,860 £28,029 £28,048

The costs have been allocated in proportion to the number of customers in each licensed network.

External £46,099 Expenditure in Previous (IFI) Internal £10,815 Financial Years Total £56,914

Total Project Costs Projected 2011/12 External £55,000 (Collaborative + costs for £1,915,000 Internal £2,000 External + UK Power Total £57,000 UK Power Networks) Networks

The projects of most interest to UK Power Networks are:  Overhead lines measurement system.  Application of artificial immune system algorithm to distribution networks.  Protection issues of inverter-interfaced DG.  Chemical approaches towards intelligent insulation.  Electrical network fault level measurement for distributed Technological Area generation and other applications. and / or Issue Addressed by Project  Reactive power dispatch using distributed generation.  Influence of oil contamination on the electrical performance of power transformers.  Alternatives to SF6 as an insulation medium for distribution equipment.  Solid state devices for electrical power distribution. Further projects related to the transmission network are also being carried out.

Significant, Project Project Residual Overall Project Technological Benefits Type(s) of Innovation Risk Score substitution Rating Involved and Radical innovations 9.4 0.0 9.4

Industry, IET and academia have agreed that the projects are Expected Benefits of beneficial to both the DNOs (through potential breakthroughs that Project could lead to new practices or products) and to academia by raising

51 the profile of power engineering.

Expected Timescale Duration of benefit Year 2012 onwards 20 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 25% Present Costs) x £200,000 Probability of Success

UK Power Networks is directly involved in the following projects:

The Overhead Line Monitoring System (OHMS) project aims to develop a system for remote measurement of power line metrics (e.g. voltage, current, fault time stamping, etc.) and is investigating the opportunity to use the power line infrastructure rather than a separate telecoms solution to relay information back to the control room. A demonstration of a new fault location scheme will be carried out with the potential to reduce CMLs on particularly vulnerable parts of the network.

Chemical Approaches Towards Intelligent Insulation It is expected that by the end of this project, polymers responsive to electrical stimuli will be proven to work in a model polystyrene system. It is hoped the model system could then be suitably adapted in the future to make an application specific smart dielectric material that will deliver:  Improved condition monitoring of dielectric materials.  Cost effective monitoring technique built into the dielectric material.  Visual response (such as colour change or fluorescence) is easily interpreted – no specialist equipment required.

Potential for Achieving Electrical Network Fault Level Measurement for Distributed Expected Benefits Generation and Other Applications A fault level monitor (FLM) that is capable of calculating the network source impedance is expected to measure network fault level to support results from EN60909 calculations. This will aid in evaluating the network for new DG connections and providing more detailed temporal data on network fault levels.

Alternatives to SF6 as an insulation medium for distribution equipment The project aims to demonstrate the use of an environmentally friendly insulation gas (CF3I) and its mixtures for application in distribution and transmissions systems. The project will involve undertaking an extensive literature survey of existing alternative insulation gases to SF6 gas and compare the properties with those of CF3I. The project will also involve the designing and setting up of experimental tests rigs for the characterisation of CF3I gas and its mixtures under various working conditions, including breakdown phenomena and current interruption properties and apply the knowledge gained from this experience to possible applications of CF3I and its mixtures to high voltage switching duties.

Additionally UK Power Networks receives benefits from the remaining projects supported by the other collaborating partners. For brevity we provide progress for the projects UK Power Networks is supporting.

Project Progress The Overhead Line Monitoring System (OHMS) project

52 March 2011 Research progress has been good and results have been positive. Relevant control techniques have been successfully applied and adapted for the cases studied. A system prototype has been designed and built. There has been substantial collaboration with UK Power Networks. Three week long placements in various parts of the company have been undertaken and field trials on decommissioned lines are at a mature stage of planning.

Chemical Approaches Towards Intelligent Insulation Initial work it was found that the electrical properties of the fluorophore doped polymers were minimally affected when compared to virgin polystyrene. A dramatic increase in intensity was observed when pyrene doped polystyrene was electrically stressed compared to virgin polystyrene during electroluminescence measurements. Further work will be necessary to determine the cause of this increased emission intensity. Currently, blends of have been synthesised and will be polarised under a DC field with any changes in colour monitored in real-time using a spectrometer. On successful completion of the polarising equipment, a whole host of materials can be tested in order to find an optimum sensing and reporting molecule.

Electrical Network FLM for Distributed Generation and Other Applications In our 2007/08 activity report we reported that the ENA R&D working group had stopped a FLM project with the intention of carrying out further work to resolve questions about the apparent differences in performance of the existing instrument and the FLM algorithms implemented in Matlab. An initial literature review detailed only one existing device and how it operated, research had begun into new algorithms for a real-time monitor but to date no new devices have been developed. Initial signal processing algorithms have been developed and this has allowed the student to become more familiar with Matlab/ Simulink. The student attended a secondment with UK Power Networks to gain experience with the distribution networks and fault levels. During the visit a sample network was developed within DigSilent power software for future comparison with the proposed fault level monitor.

Alternatives to SF6 as an insulation medium for distribution equipment The project is at the initial literature review and scoping phase involving discussions with DNOs, manufacturers and research trends undertaken on CF3I.

EPSRC, The IET and the following industrial partners: Collaborative Partners Western Power Distribution, EA Technology Ltd, National Grid and Scottish and Southern Energy

Universities of Cardiff, Manchester, Queens (Belfast), Southampton, R&D Providers Strathclyde, and Imperial College London

53 Vegetation Management

This project’s overall goal was to provide an improved understanding of vegetation growth and the way in which it encroaches on the safety space around electrical equipment, known as the utility space (US).

Description of Project This project is monitoring vegetation growth at 1300 sites across the UK network and integrating the national database of vegetation growth into existing vegetation management systems to promote an efficient, spatially and climatically sensitive management of vegetation.

Expenditure for EPN LPN SPN Financial Year External £43,662 £0 £15,651

Internal £4,200 £0 £1,505

Total £47,862 £0 £17,156

Costs have been allocated in proportion to length of overhead line.

External £334,243 Expenditure in Previous (IFI) Financial Years Internal £30,553

Total £364,796

Total Project Costs External £16,662 Projected 2011/12 costs for (Collaborative + External £ 1,740,000 Internal £2,000 UK Power Networks + UK Power Networks) Total £18,662

Technological area and / or issue Addressed by Arboriculture; rate of vegetation growth. Project

Project Benefits Project Residual Overall Project Type(s) of Innovation Significant Rating Risk Score Involved 17.8 1 16.80

The expected benefits include an integration of results into existing vegetation management processes, that will enable UK Power Expected Benefits of Networks and other collaborating DNOs to determine cutting patterns Project and cycle lengths based on potential risks, and hence allowing multiple savings.

Expected Timescale to Duration of benefit once Year 2012 20 Years Adoption achieved

Project NPV (Present Probability of Success 70% Benefits – Present Costs) x >£4,000,000 Probability of Success

Measurements are now complete. The project is therefore in its final stage which will consist of data analysis, production of a final report Potential for Achieving and dissemination of results to the project partners. Expected Benefits

The main body of the project has progressed well with only a slight

54 delay due to extreme weather conditions in late 2010. Further work is required to integrate results into existing vegetation management procedures; the potential for achieving expected benefits of optimisation are high.

Meteorological records covering the UK for the past 40 years have been analysed to create a complete set of bioclimatic zone maps for the UK. We have surveyed 2500 potential study sites, across the country, for suitability within this project and we currently have a network of approximately 1300 sites participating in the study. We have measured US closure in the Spring and Autumn of 2008, 2009 and 2010 at all sites and have created a substantial dataset that describes the spatial variation of vegetation growth across the UK.

The vegetation database created by this project covers all major bioclimatic zones in the UK, shown in Figure 9. There is considerable variation in growing environments across the country.

Final results indicate a national annual average change in US of 0.96m (±0.03 se.) but with considerable variation by location in the country. This average figure is consistent with the preliminary value determined after the first year growth; however there was a notable shift in the values determined for individual Project Progress partner companies during the March 2011 following two years of the project. Of particular note – the annual average figure for National Grid sites based on the first years growth dropped Figure 9 – National Map from1.76m (±0.15 s.e.) to of Bioclimatic Zones 1.58m (±0.06 s.e.) for the entire study period.

This project broadly found that sites located in the warmer areas of Southern England, encompassed within the National Grid and UK Power Networks (SPN) study sites, experienced the average highest rates of growth with the lowest observed at relatively cooler ScottishPower (Scotland) sites. Some of this variation inevitably arose from differences in management practice but the results from this work show a very clear spatial pattern to US degradation following bioclimatic zone lines that indicates a potentially powerful mechanism to target vegetation management.

The frequency with which an individual vegetation type was the closest to the infrastructure at a study location and therefore was the species immediately responsible for determining US was also noted; results showed considerable variation. However, Hawthorn was found to be the species most commonly closest to the line.

Electricity North West, SP Energy Networks, Western Power Collaborative Partners Distribution, National Grid

R&D Provider ADAS

55

Tree Growth Regulator

The project is investigating the effect of a plant growth regulator (TGR) on tree vitality and growth rates. Six field trial sites have been established, supported by 13 observational sites throughout the UK to represent a diverse range of bio-climatic zones. There are two sites Description of Project in each of the participating network operator’s licence areas. Tree species selected for TGR evaluation were selected to represent those that occur commonly on or near overhead networks, and where both the landowner and the DNO may find mutual benefit in using TGRs to manage growth and health of trees.

Expenditure for EPN LPN SPN Financial Year External £12,952 £0 £4,642

Internal £1,327 £0 £476

Total £14,279 £0 £5,118

Costs have been allocated in proportion to length of overhead line.

External £52,766 Expenditure in Previous (IFI) Internal £7,594 Financial Years Total £60,360

Total Project Costs Projected 2011/12 External £20,000 (Collaborative + £ 715,000 costs for UK Power Internal £4,000 External + Networks Total £24,000 UK Power Networks)

Technological Area Ability of Tree Growth Regulators to manage rate of vegetation and / or Issue growth and reduce maintenance costs, whilst improving vitality of Addressed by Project vegetation.

Project Benefits Project Residual Overall Project Type(s) of Innovation Significant Rating Risk Score Involved 15.4 -2 17.4

The expected outputs from the project will be data and information on the effect of PBZ on tree growth rates across a range of species and bioclimatic areas. This data will comply with ORETO experimental requirements and will be used to apply for a licence for the use of PBZ for utility vegetation management. Expected Benefits of Project PBZ could then be used as part of utility vegetation programmes to reduce growth rates on restricted cut sites and reduce overall vegetation management costs. This would also reduce the disturbance to landowners and the high costs of returning each year to maintain clearances from locations where only a restricted cut is possible.

Expected Timescale Duration of benefit Adoption in 2014 20 Years to Adoption once achieved

56 Project NPV (Present Benefits – Probability of Success 75% Present Costs) x >£1,000,000 Probability of Success

The purpose of the first year’s measurements was to demonstrate whether over application of TGR and subsequent damage of leaf material occurred. No statistically significant difference was found between TGR treated and control trees, which indicates that there were no symptoms of damage in leaf tissue during the 2009 growing season.

In year two, a significant influence of TGR on growth and vitality was Potential for Achieving recorded in the majority of trees at each field and observation site; Expected Benefits manifest by reduced shoot growth and trunk diameter and subsequent increase in root growth. With respect to tree vitality, effects were increased leaf photosynthetic activity, greener leaves and plant cell wall strength. Consequently, all objectives stipulated in the IFI research project have, to date, been achieved. In addition, no particular factors can be foreseen which would result in delays in the achievements of any of the stated objectives in the original research proposal. Measurements in subsequent years will continue to investigate the potential for reduction in utility tree growth rates.

The PSD has granted an experimental licence and the work has been set up to meet ORETO research guidelines. An audit carried by ADAS compliance team confirmed that the experiment complies with these guidelines.

Six field sites and thirteen observational sites have been set up and TGR applied at recommended dosage rates. Initial observations have indicated no phytotoxic (damaging) effects.

Following discussions with the DNO Project Director further planting of the popular tree species Leylandii and Alder occurred on two sites in early 2010, they were treated with TGR during summer 2010.

In 2010, both field and observational site data indicate a significant Project Progress positive benefit of TGR application on tree vitality and growth. In TGR March 2011 treated trees reduced shoot growth and trunk diameter, and increased root growth was recorded. With respect to tree vitality, TGR effects were manifest as an increase in leaf photosynthetic activity resulting in greener leaves and reduced electrolyte leakage.

Effects of TGR on vitality and growth varied between tree species with some species such as English oak and beech particularly sensitive while other such as poplar and willow far less sensitive.

UK Power Networks have started an information-only exercise to gauge customer opinion and acceptance of this new to the UK tree treatment. The survey population are those who will benefit from use of the new treatment on their trees if/when the licence for its use in utility vegetation management is granted.

Scottish and Southern Energy, Western Power Distribution, CE Collaborative Partners Electric UK

R&D Provider Bartlett Tree Experts, ADAS

57 GIS Data Definition

UK Power Networks holds information on the location of its network assets in a Geological Information System (GIS) called NetMAP. It is the primary asset register for the UK Power Networks cable and overhead line network, and provides location details for the rest of the Network assets. NetMAP holds geospatial information for all three licence (EPN, SPN and LPN) areas and is one of the four core systems used within UK Power Networks. In SPN the data is held as vector [digitised format]. However both LPN and EPN hold the data as a combination of vector and raster (photographic images). Description of Project A proof of concept (PoC) was undertaken to see if it was possible to utilise a number of external, disparate data sources [Inspection data, Non-geographic asset records, LIDAR measurements and aerial photography] to improve the records in NetMAP. The PoC proved that this was possible with the development of a semi automated tool that would pull the suitable data sources into NetMAP, and allow the users, Network Records staff, to decide which pieces of data should be combined to create a composite vectorised record containing the best representation of the asset.

Expenditure for EPN LPN SPN Financial Year External £84,609 £0 £0

Internal £74,857 £0 £0

Total £159,466 £0 £0

The costs have been allocated to EPN.

Expenditure in Previous New Project 2010/2011. (IFI) Financial Years

Total Project Costs Projected 2011/12 (Collaborative + £280,929 costs for UK Power £120,000 External + Networks UK Power Networks)

The proof of concept is developing the following techniques:  The intelligent and accelerated conversion of the HV and EHV overhead network for Luton, Stevenage and Hemel Hempstead. Technological Area and  The approach also ensures, where possible, that the Ellipse ID / or Issue Addressed by is populated in each object thereby linking NetMAP to Ellipse Project (the UK Power Networks Asset Register).  This also enabled the development of a tool to link Ellipse to NetMAP.

Project Project Residual Overall Project Benefits Type(s) of Innovation Risk Score Incremental Rating Involved 11 -4 15

Benefits are expected to include:  Records are easier to maintain. Expected Benefits of  Assets are separated from the base map. Project  Assets are easier to view and control.  Most importantly, the data is intelligent [count, measure].

58 Expected Timescale to Duration of benefit 9 months 3 years Adoption once achieved

Project NPV (Present Benefits – Present Probability of Success 90% £72,750 Costs) x Probability of Success

Work is currently on-going to continue the EPN overhead line HV and Potential for Achieving EHV conversion from Raster to Vector in UK Power Networks. This Expected Benefits will ensure that the technologies developed as part of this project can be utilised to their full potential.

Project Progress The proof of concept is ongoing. March 2011

Collaborative Partners n/a

R&D Provider n/a

59 Transformer Oil Health Index Tool (closed)

UK Power Networks identified the need to apply a systematic approach to interpreting results of transformer Dissolved Gas Analysis (DGA). This project provides an online tool to calculate a Description of Project Health Index score for major transformers, tapchanger selectors, reactors and auxiliary transformers based on new and historic test results.

Expenditure for EPN LPN SPN Financial Year External £9,136 £3,819 £5,044

Internal £1,922 £803 £1,061

Total £11,058 £4,623 £6,106

For simplicity, the costs have been allocated in proportion to Grid/primary transformers.

Expenditure in Previous (IFI) New Project 2010/2011 Financial Years

Total Project Costs (Collaborative + Projected 2011/12 costs for UK Power Project External + £21,977 Networks closed UK Power Networks)

 Using DGA results to calculate a Health Index Score for Technological Area Major Transformers and associated plant. and / or issue  Analysing trends in results over a 10 year period to calculate Addressed by Project score.

Project Benefits Project Overall Project Type(s) of Innovation Increment Rating Residual Risk Score Involved al 12 -12 24

 Reduced interpretation time from application of a systematic Expected Benefits of approach to analysing results Project  Use of historic data to measure asset health trends

Expected Timescale 2011 Duration of benefit once achieved 10 years to Adoption

Project NPV (Present Benefits – Probability of Success 70% £1000 Present Costs) x Probability of Success

Project complete however Health index is calculated on most recent Potential for Achieving results only. Historic results are trended in graph form for each asset Expected Benefits for further manual analysis.

The Transformer Oil Analysis Tool has been delivered to UK Power Project Progress Networks. New DGA results are uploaded to the tool periodically March 2011 following upload to the asset register.

Collaborative Partners n/a

R&D Provider EA Technology

60

Visible Flexible Networks

61 Visible Flexible Networks

Contents

AURA NMS – Autonomous Regional Active Network Management System ...... 63 Supergen 1 – FlexNet ...... 65 Algorithmic Automation ...... 69 The Zefal Generator for Active Urban Networks (ZEFAL) (closed)...... 71

62 AURA NMS – Autonomous Regional Active Network Management System

The project developed a distributed control system to deliver:  Real-time automated reconfiguration, initially to a regional network of up to four primary substations. Description of  Methods to economically, efficiently and effectively integrate large Project amounts of small scale distributed generation taking into account legacy infrastructure and renewal programmes.  Network optimisation taking into account DG and Electrical energy storage.

Expenditure for EPN LPN SPN Financial Year External £359,370 £256,518 £231,407

Internal £33,071 £21,135 £21,149

Total £392,441 £277,653 £252,556

The costs have been allocated in proportion to the number of connected customers.

External £2,284,486 Expenditure in Previous (IFI) Internal £227,854 Financial Years Total £2,512,340

Total Project Costs (Collaborative + External £225,000 Projected 2011/12 costs External + £5,760,000 Internal £5,000 for UK Power Networks UK Power Total £230,000 Networks)

The scoping and development of three major areas.  Measurement of Distributed Generation and demand side Technological Area management to facilitate the connection of DG to the network. and / or Issue  Develop a controller that will monitor electricity networks, isolate Addressed by faults quickly and allow distributed generation to remain connected Project and operating.  Optimise the network with respect to losses, where distributed generation is concerned.

Project Project Residual Overall Project Benefits Type(s) of Risk Score Radical Rating Innovation Involved

11.8 5 6.8

The technologies under review have potential to deliver benefits in a number of areas:  Maximisation of the contribution of DG to the electricity network;  Reduction in carbon emissions and help towards the UK government’s climate change targets. Expected Benefits  Reduction in network losses by having the source of generation close of Project to the load.  Improvement in quality and security of supply.  Improvement in network resilience.  Reducing the current market failures to increase network capacity for DG.

63 Expected Duration of benefit Timescale to Year 2015 20 Years once achieved Adoption

Project NPV (Present The technologies are Probability of Benefits – Present expected to deliver benefits 25% Success Costs) x Probability of in the order of millions of Success pounds in the long term.

Potential for The research phase has closed, but field trials at three primary Achieving Expected substations are continuing to collect data. Benefits

The restoration agent developed during the research phase was downloaded to ABB’s COM600 substation automation device installed in three substations near Redhill in Surrey. Whilst the device will not carry out any automation, the first step will be to examine extras it would have taken.

An open dissemination event was held in June 2010 at Imperial College to report results to the wider industrial and academic community in the UK through talks, demonstrations and posters. The demonstrations included running the substation control algorithms developed by the partner universities on the ABB target hardware and interacting with a real-time network simulation. The event was attended by 110 people and Project Progress feedback received showed that the material presented was of great March 2011 interest.

An energy storage device has been installed and commissioned at Hemsby, Norfolk. The experiences of its installation were discussed at CIRED 2011. The installation is now being used to demonstrate the value of energy storage as a Low Carbon Networks Fund tier 1 project. The energy storage device has been widely reported in many engineering publications including Transmission and Distribution World.

UK Power Networks are planning a second phase to monitor and analyse the output of the agents as the installation took longer than anticipated. This will lead to a better understanding of the balance between centralised and distributed network management.

Collaborative This was a Strategic Partnership between the EPSRC, ABB, Partners ScottishPower Energy Networks

Aura NMS is led by Imperial College London and supported by the R&D Provider Universities of Bath, Cardiff, Durham, Edinburgh, Loughborough, Manchester and Strathclyde

64 Supergen 1 – FlexNet

FlexNet is a four year (2007-11) programme focused on seven themes. Of these ‘Intermittency’, ‘System Operation’ and ‘Multi- terminal High Voltage Direct Current (HVDC) Systems’ are particular challenges for the UK Government’s 2020 Low Carbon Transition Plan (LCTP). The other themes: ‘A More Electric Future’, ‘Visions Description of Project and Scenario’, ‘Customer Participation’ and ‘Active Distribution’ are topics that prepare for the 2030 onwards agenda. The uncertainty of the future means that flexibility continues to be an important objective. The programme aims, where possible, to showcase its insights and achievements so that these can be taken up by the commercial sector, government and regulators for practical implementation.

Expenditure for EPN LPN SPN Financial Year External £8,778 £5,609 £5,613

Internal £879 £562 £562

Total £9,657 £6,171 £6,175

The costs will be allocated in proportion to the number of customers in each licensed network.

External £40,000 Expenditure in Previous (IFI) Internal £16,770 Financial Years Total £56,770

Total Project Costs Projected 2011/12 External £20,000 (Collaborative + costs for £ 7,500,000 Internal £3,000 External + UK Power Total £23,000 UK Power Networks) Networks

The issues being addressed by the work-streams and reported under each of the themes are as follows:  Intermittency – The 40% renewable electricity target will be met mainly by wind energy (intermittent generation). This creates challenges for system balancing and security of supply. This research aims to ensure that cost-effective integration of wind generation is achieved.  System Operation – FlexNet’s planned research in system operation is proving well-aligned with the Electricity Networks Strategy Group (ENSG) and Energy Technologies Institute (ETI) Technological Area reports. The work is focused on building a modelling and and / or issue analysis base for testing increased boundary transfer limits and Addressed by Project of corrective post-fault control. The planning of strategic network investment beyond 2020 is key topics currently being pursued.  Multi-Terminal HVDC Systems – This theme re-focuses on power systems electronics in response to the growing development of offshore renewable generation exploitation of which will require a departure from conventional AC-based transmission. To date, HVDC deployment has been limited to point-to-point connections; realisation of DC networks will require significant research into both control methodologies and underlying hardware.

 More Electric Futures – The dramatic cuts in CO2 in the

65 electricity sector require radical changes. This work investigates these changes and examines the implications for the energy networks through five projects. The first project addresses the demand placed on the electricity system in UK from the increased use of electricity as the vector for energy transmission and distribution. The second project looks at how significantly increased electricity use should be accommodated within the UK power system.  Visions and Scenarios – The work carried out for FlexNet supported the ‘Long-term Electricity Network Scenarios (LENS) project.  Customer Participation – The emphasis here is on the end use of electricity in economic, technical and human sense. Work is being undertaken on engaging consumers about the necessary transition towards the 2020 objectives. This is focused on understanding how people view the electricity supply system and their flexibility in interfacing with it.  Active Distribution – The work examines the distribution planning problem as a stochastic maths programme. Work is underway on control room interfaces for active networks, and on an active power distribution network and data acquisition simulator/emulator.

Project Project Residual Overall Project Type(s) of Innovation Radical Residual Risk Risk Score Involved 7.2 -2 9.2

Each area of FlexNet’s work is delivering benefits and expected to deliver further benefits as highlighted below:  System Operation – Insights gained will be showcased through grid models, flexible protection and control platforms including WAMS, and demand-side data sets.  Multi-Terminal HVDC Systems – Control system designs for power flow regulation in MT-HVDC have been established and tested in standard power system simulators.  More Electric Futures – This theme has already contributed evidence for policy development through the LENS project.  Visions and Scenarios – The outputs of the LENS scenario have Expected Benefits of been used in various responses for the fifth Distribution Price Project Control Review; the OFGEM ‘RPI-X@20’ project; National Grid in their ‘Operating the Electricity Transmission Networks in 2020’ consultation (June 2009); the Gone Green scenario (Nov 2008); as well as a joint Electricity Networks Futures Group (ENFG) and Energy Networks Association (ENA) project which is seeking to understand the long term (2020-2030) requirements for distribution systems.  Customer Participation – To achieve the envisaged decarbonisation of the electricity sector beyond 2030, most of the demand for electricity will need to be able to align itself with the availability of carbon-free generation. The work programme across FlexNet is developing some of the key enablers for this objective including self-regulating buildings, electricity market designs catering for flexible demand.

66 Expected Timescale Duration of benefit Year 2012 onwards 20 Years to Adoption once achieved

Project NPV (Present Benefits – The project is delivering Probability of Success 25% Present Costs) x significant benefits in Probability of informing policy Success

FlexNet will produce a number of PhD graduates who will be familiar with issues associated with distribution and transmission networks. Potential for Achieving The new concepts, techniques, prototypes and demonstrations will Expected Benefits inform network operators of the options that could become available in the next few years.

The project has completed 3.5 years of its 4 year programme and most work has reached the stage of producing conclusions on the basis of its simulation models and experimental tests. The training programme is also nearly complete with a series of discipline crossing training courses and industrial placements undertaken for researchers. The progress reported here concentrates on task completed in the last 12 months:  Intermittency – New techniques and algorithms have been used to assess the ability of demand side flexibility and interconnections to (i) ‘firm up’ intermittent renewables, hence increasing the capacity value of intermittent generation and reduce backup requirements; and (ii) to reduce the need for operating reserves and flexible generation, enhancing the operating efficiency of the system and the ability of the system to absorb intermittent generation. An approach to bidding wind power in a competitive market has been produced.  System Operation – a WAMS demonstration platform has been completed and proposals made for the use of corrective control options. The operation of a system with series compensation and HVDC bootstraps has been modelled and the provision of damping in such as system investigated. An adaptive auto- recloser scheme has been demonstrated. Project Progress March 2011  Multi-Terminal HVDC Systems – Laboratory demonstration of multi-terminal operation has been achieved. Detailed control schemes have been established for multi-module power converters and tools produced for assessing the power loss of these structures. Some specific proposals have been made for control and operation through AC and DC side faults.  Customer Participation – Demonstrations have been completed on frequency responsive home appliances and of building energy management systems that respond to local network conditions and energy prices. A study of deliberative engagement taking an example at Nailsea on the reinforcement route from Hinckley Point has led to conclusions on how a community perceives the information present on route options.  More Electric Future – The linkages between electricity and heat distribution systems have been explored using a case study in EBBW Vale.  Active Distribution Networks – Experimental evidence has now been provided that the hybrid tap changer extends contact life into millions of operations and a fast switch actuator has been prototyped. The soft-open-point has been assessed in simulations of 12 example networks and the control system is also being tested in a laboratory example. Fault current analysis

67 of inverter DG has been experimentally verified and a procedure for calculating such fault currents established. Existing protection policies have been tested against a large number DG scenarios to established where and when such policies may need revision. Proposals have been made for adaptive protection regimes. A demonstration of a control room display incorporating active management schemes has been completed.

EPSRC and the following industrialists: Collaborative Partners CE Electric UK, Western Power Distribution, National Grid, ScottishPower Energy Networks, Scottish and Southern Energy

University of Bath, University of Birmingham, University of Cambridge, Cardiff University, University of Durham, University of R&D Provider Edinburgh, University of Exeter, University of Manchester, University of Strathclyde, Imperial College London

68 Algorithmic Automation

UK Power Networks have made extensive use of a hard-coded script automation system, which has had a significant positive impact on its Quality of Supply performance. This system automatically responds to a source circuit breaker tripping by locating the fault using Fault Passage Indicators (FPI), isolates the fault using pre-programmed remote control switches along the feeder, and finally restores as many customers as possible by closing either the normal open point or source feeder circuit-breaker.

While this system has been successful in reducing fault durations to customers, it has a number of drawbacks, such as:  Each automated feeder requires a hard-coded script to be written. Description of Project  Only switches declared in the hard-coded script can be controlled by the system.  When a feeder is running abnormally, the automation has to be disabled.

UK Power Networks is working with GE Energy to implement a more intelligent system of automation, known as algorithmic automation, into a standard off-the-shelf product. This new system will be based on a global algorithm, and will allow any remote controlled switch on the network to be used in the fault detection, isolation and restoration process. This system will be fully supported by and integrated into the Power On Fusion network management system used by UK Power Networks.

Expenditure for EPN LPN SPN Financial Year External £132 £84 £84

Internal £5,056 £3,231 £3,234

Total £5,188 £3,316 £3,318

The costs have been allocated in proportion to number of customers.

Expenditure in Previous (IFI) New project 2010/2011 Financial Years

Total Project Costs Projected 2011/12 (Collaborative + costs for UK Power £225,000 External + £1,000,000 Networks UK Power Networks)

Technological Area  The automatic reconfiguration of the distribution network and / or issue following a fault. Addressed by Project  Impacts of HV faults on the distribution network.

Project Benefits Project Residual Overall Project Type(s) of Innovation Incremental Rating Risk Score Involved 12 -3 15

69 Benefits are expected to include:  Reduction of impact to customers of HV faults.  Reduction in CMLs. Expected Benefits of  Reduction in CIs. Project  Reduction in customer complaints.  Reduction of time spent administering the current automation system.

Expected Timescale Duration of benefit Year 2012 DPCR5 + to Adoption once achieved

Project NPV The NPV is currently (Present Benefits – being assessed; it is Probability of Success 75% Present Costs) x likely to be in the Probability of millions. Success

Potential for Achieving The project has significant potential and readily fits in with our regular Expected Benefits update cycle for our network management system.

A project plan has been developed and resources identified. Likely to Project Progress be one of our key strategic projects and one which requires significant March 2011 investment which we are prepared to input.

Collaborative Partners n/a

R&D Provider None

70 The Zefal Generator for Active Urban Networks (ZEFAL) (closed)

Development of a proof-of-concept prototype generator that is Description of Project optimised for network connectivity, including networks with fault level constraints.

Expenditure for EPN LPN SPN Financial Year External £0 £4,343 £0

Internal £0 £5,683 £0

Total £0 £10,026 £0

The costs have been allocated to LPN licensed area where the ZEFAL generator would be expected to deliver the most benefit.

External £23,000 Expenditure in Previous (IFI) Internal £16,940 Financial Years Total £39,940

Total Project Costs Projected 2011/12 (Collaborative + costs for £ 430,000 Project Closed. External + UK Power UK Power Networks) Networks

Technological Area Methods for connection of distributed generation where network and / or issue constraints exist. Addressed by Project

Project Benefits Project Residual Overall Project Type(s) of Innovation Radical Rating Risk Score Involved 7 3 4

The ZEFAL project aims to facilitate increased levels of distributed Expected Benefits of generation resulting in reduced carbon emissions from energy. Project Connection requests using this type of generator will be simpler for the DNO to assess.

Expected Timescale Duration of benefit Year 2016 10 Years to Adoption once achieved

Project NPV The project has potential (Present Benefits – to deliver benefits to both Probability of Success 95% Present Costs) x generation developers Probability of and DNOs Success

A patent has been registered for the design. It is expected to provide competitive advantage over existing products. Potential for Achieving

Expected Benefits It has also provided benefit in understanding the technologies involved and shaping them to the needs of the DNOs.

71 The project has delivered a working ‘proof of concept’ prototype that has been witness tested at NaREC’s site in Blyth. The tests were successful and the prototype demonstrates the technology developed during the project – providing a greatly reduced current contribution to a fault compared with a standard machine.

These tests covered both balanced and unbalanced faults with different profiles. Machine tests were conducted with very low Project Progress impedance faults and detection systems were tested with ‘less March 2011 obvious’ faults and voltage recovery profiles.

The Zefal Patent was registered on 31st Jan 2011 and the project final report has been distributed to the partners involved.

Various possibilities for a ‘round 2’ project are being investigated with various generator manufacturers and funding bodies / sources. This would build on the work carried out so far to develop a fully rated device that would be suitable to install on a distribution network.

Collaborative Partners Western Power Distribution, CE Electric UK

NaREC Development Services Ltd, PPA Energy Ltd, University of R&D Provider Nottingham, Imperial College London

72 Full Fault Knowledge

73 Full Fault Knowledge

Contents

LV Remote Control and Automation ...... 75 Overhead Line Incipient Fault Detection ...... 77 Helicopter Mounted Partial Discharge Locator...... 79 LV Underground Cable Fault Management (closed)...... 81

74 LV Remote Control and Automation

This project aims to provide a complete solution to automate and monitor the Description of low voltage network. Retrofittable load break/fault make switches for Project underground link boxes will be developed, as well as fault break/fault make circuit-breakers for low voltage panels in substations.

EPN LPN SPN Expenditure for Financial Year External £21,734 £12,430 £14,327

Internal £2,542 £1,454 £1,676

Total £24,276 £13,884 £16,003

The costs have been allocated in proportion to length of installed LV cables.

External £160,334 Expenditure in Previous (IFI) Internal £7,594 Financial Years Total £167,928

Total Project Costs (Collaborative + Projected 2011/12 External £680,000 External + £ 912,581 Costs for UK Power Internal £10,000 UK Power Networks Total £690,000 Networks)

Technological Area and/or Issue Management of the low voltage network Addressed by Project

Project Benefits Project Residual Overall Project Type(s) of Significant Rating Risk Score Innovation Involved 16.2 -2 18.2

The main benefits expected are as follows:  Improved safety for public and utility engineers by using arc-free switching technology and novel fault make switching capability. Expected Benefits  Remote and rapid restoration of supplies. of Project  Reduction of Customer Minutes Lost (CML) and Customer interruptions (CI).  Better understanding of power flows, network load monitoring.

Expected Duration of Benefit Timescale to 3 Years 10 years Once Achieved Adoption

Project NPV (Present Benefits – Probability of 75% Present Costs) X £3,100,00 Success Probability of Success

Potential for Development is at an advanced stage and field trial deployment will Achieving Expected commence during Q3 2011. Benefits

75 Short Duration Withstand Capability Testing  400A fuses will be used in series with the circuit-breaker solid state switching technology to offer backup protection. It will also provide protection for higher fault levels beyond the rating of solid state devices.  Tests on 400A JPU fuses have established that fault currents are limited to 31.5kA peak even when the prospective fault current is over 70kA rms or 175kA peak.  Prototypes have successfully withstood peak currents up to 35kA peak.  Link box switches and circuit-breaker prototypes have been designed and built using contact technology to achieve these ratings.

Operational Tests  Temperature rise tests at 400A have been successfully conducted on switches installed in link boxes.  Open/close operations up to 1000 cycles have been performed.

Remote Control Electronic circuits to operate the devices in both local and remote mode have been developed and are being tested. Project Progress March 2011 Software  The development of the control system is at an advanced stage with initial screens for remote control developed and tested.  System integration tests started on test bench with three link boxes connected to a single substation outlet.

Figure 10 – LV Automation Control Software

Collaborative TE Connectivity (formerly Tyco) Partners

R&D Providers TE Connectivity (formerly Tyco)

76 Overhead Line Incipient Fault Detection

This project aims to develop an integrated solution to locate and characterise faults on overhead lines, based on waveform analysis and substation monitors installed on the HV overhead network. Description of Project The objectives are to:  Help identify more rapidly network sections containing faults.  Predict and accurately locate a potential fault on the system before it occurs.

Expenditure for EPN LPN SPN Financial Year External £60,931 £0 £21,841

Internal £5,317 £0 £1,906

Total £66,248 £0 £23,746

The costs have been allocated in proportion to the length of high and low voltage overhead lines combined in each region.

External £213,160 Expenditure in Previous (IFI) Internal £18,213 Financial Years Total £231,373

Total Project Costs Projected 2011/12 External £6,000 (Collaborative + £329,221 costs for UK Power Internal £1,000 External + Networks Total £7,000 UK Power Networks)

 Overhead line fault mechanisms and whether they are Technological Area associated with recognisable, repeatable waveforms. and / or Issue  The location of faults based on measuring time-of-arrival of the Addressed by Project waveforms.

Project Benefits Project Residual Overall Project Type(s) of Innovation Radical Rating Risk Score Involved 16 0 16

The expected benefits of the project are: Expected Benefits of  Development of a proactive approach towards decreasing Project interruption duration.  Reduced the switching required to locate faults.

Expected Timescale Duration of benefit 2014 10 years to Adoption once achieved

Project NPV (Present Benefits – This is being evaluated Probability of Success 25% Present Costs) x as part of the project Probability of Success

77 The project has developed and installed a prototype system on four 11kV circuits and five 33kV circuits. Data has been collected successfully and some of the principles of event location have been demonstrated.

Results to date suggest that different fault types have different, but recognisable characteristics. Initial location trials on simple circuits Potential for Achieving have been encouraging, but further work on more complex Expected Benefits distribution networks and in variable weather conditions and environments remains a challenge.

The solution requires further development beyond the prototype stage, with further work needed on hardware and software optimisation and signal processing enhancements. The influence of local weather is more complex than anticipated, which would also require further study.

The principles of live dual-ended GPS synchronised event location have been demonstrated with good target accuracy and suitable signals can be obtained from a wide variety of plant items in event of a fault.

Recent work has focused on the enhancement of the signal processing functionality associated with the solution to improve the accuracy with which the location of circuit events can be detected, and to improve the efficiency with which signals are stored and processed.

Project Progress Event counts from all the 11kV circuits have been seen to exhibit March 2011 strong correlation with both wind and rainfall at different times. The influence of local weather conditions is both greater and more complex than anticipated and needs separate study in order to remove it from the baseline and uncover genuine incipient faults.

A prototype system has been developed to analyse event patterns based on the lessons learnt from the characterisation of known defects undertaken at Cardiff University; which requires further optimisation and long run validation. A business case for the continued development of a production version of the OLIF solution in further phases is being reviewed internally.

Collaborative Partners n/a

Cardiff University via TSB Knowledge Transfer Partnership, PPA R&D Provider Energy, EDF R&D

78 Helicopter Mounted Partial Discharge Locator

This project aims to mount a radiometric partial discharge (PD) locator to a helicopter and automate the analysis of data to allow fast Description of Project screening of potential PD defects during normal overhead line patrol flights.

Expenditure for EPN LPN SPN Financial Year External £20,973 £0 £7,518

Internal £1,994 £0 £715

Total £22,967 £0 £8,232

The costs have been allocated in proportion to the length of all overhead cables.

Expenditure in Previous (IFI) New project 2010/2011 Financial Years

Total Project Costs Projected 2011/12 External £30,000 (Collaborative + £ 66,488 costs for UK Power Internal £5,000 External + Networks Total £35,000 UK Power Networks)

Technological Area Improved management of assets: detection of overhead line and and / or Issue substation equipment defects. Addressed by Project

Project Project Residual Overall Project Type(s) of Innovation Benefits Incremental Risk Score Involved Rating

12 -9 21

Benefits are expected to include:  Avoidance of major disruptive incidents.  Ability to carry out surveys on sites before major work Expected Benefits of (Switchboard replacement, major refurbishment, etc.) Project commences, hence reducing risk to staff.  Overhead line and substation condition assessment.  Improved productivity: no requirement to fund separate flights as technology will be used during scheduled patrol flights.

Expected Timescale Duration of benefit 2011 10 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 75% Present Costs) x £470,000 Probability of Success

Potential for Achieving The project is proceeding according to plan and the expected benefits Expected Benefits are expected to be delivered.

79

All parts of the partial discharge locator, including the airframe fittings and the electronic hardware, have been designed according to EASA rules and are presently in production.

Mounting Frame

Antenna

Project Progress Figure 11 – Antenna Connected to the Mounting Frame March 2011

Figure 12 – Recording Unit

A trial fit for the PD locator is anticipated in during Q2 2011, with the first trial flight occurring shortly afterwards.

Collaborative Partners Western Power Distribution, Scottish and Southern Energy

R&D Provider Elimpus

80 LV Underground Cable Fault Management (closed)

UK Power Networks identified opportunities to improve the detection and Description of Project location of intermittent faults on LV underground cables.

This project combined the use of an intermittent cable fault location device (T-P22) with an improved re-energisation device (REZAP Fault Master) so that LV intermittent faults can be better managed and customer interruptions reduced.

EPN LPN SPN Expenditure for Financial Year External £14,051 £8,036 £9,263

Internal £1,458 £834 £961

Total £15,509 £8,870 £10,224

The costs have been allocated in proportion to the length of installed LV cable.

External £369,865 Expenditure in Previous (IFI) Internal £44,460 Financial Years Total £414,325

Total Project Costs Projected 2011/12 (Collaborative + £448,928 costs for UK Power Project closed External + Networks UK Power Networks)

The project has developed the following techniques: Technological Area  Time reflection to determine fault location. and/or Issue  Transient impedance fault location. Addressed by Project  Travelling wave fault location.  An auto reclosing device.

Project Benefits Project Residual Overall Project Type(s) of Innovation Rating Risk Score Radical Involved 16.2 -11.00 27.20

The expected benefits of this project were:  Reduction in number of site visits to replace fuses. Expected Benefits of  Reduction in repeated customer interruptions due to intermittent Project faults being re-energised.  Reduction in customer’s minutes lost.  Reduction in worst served customers.

Expected Timescale Duration of Benefit 2011 20 Years to Adoption Once Achieved

Project NPV (Present Benefits – Probability of 75% Present Costs) x £1,200,000 Success Probability of Success

81 Potential for Achieving Expected This project is now closed. Benefits

T-P22 (intermittent fault location equipment): Development has been carried out to enhance the capabilities of the T- P22 software and integrate it into a web based management solution. A pilot showed a success rate of over 85% in the EPN region.

REZAP Fault Master (LV auto-reclosing equipment): The REZAP is routinely being used by UK Power Networks staff before Project Progress replacing LV fuses. It is expected that the functionalities developed as March 2011 part of this project (e.g. ‘distance to fault estimation’, load profiling, etc.) will contribute to more efficient fault location and restoration of supplies.

Modular REZAP UK Power Network contributed to the early development stages of this equipment. It offers a more compact solution than the REZAP and can be used inside outdoor LV pillars. This product has now been developed and is available commercially.

Collaborative Electricity North West, ScottishPower Energy Networks Partners

R&D Provider Kehui Ltd, Kelvatech, Nortech Management Ltd.

82 Optimal Network Operation

83 Optimal Network Operation

Contents

Optimal Transformer Utilisation Model (closed) ...... 85 Strategic Technology Programme: Module 2: Overhead Networks: 2010/2011 ...... 87 Strategic Technology Programme: Module 3: Cable Networks: 2010/11...... 89 Strategic Technology Programme: Module 4: Substations: 2010/11 ...... 92 Strategic Technology Programme: Module 5: Networks for Distributed Energy Resources: 2010/11...... 95 Collaborative ENA R&D Programme ...... 98 Network Risk Management (closed) ...... 102 Active Distribution networks with full integration of Demand and distributed energy RESourceS (ADDRESS) ...... 104 Transformer Design for FR3 ...... 106 Vacuum Tap Changer (closed) ...... 108 Recycling Excavated Material (closed) ...... 110 Lone Worker Risk Management (closed)...... 112 Multiple Cable Ratings in Ventilated Tunnels (closed)...... 114 Advanced Harmonic Monitoring...... 116

84 Optimal Transformer Utilisation Model (closed)

UK Power Networks currently models cyclic ratings and emergency ratings of power transformers by using a method based on formulae described in the standards document CP1010 / BS7735 (A Loading Guide For Oil Immersed Transformers). This model allows the load- related risk on a substation to be quantified in order to prioritise network reinforcement expenditure. The model predicts the temperature rise within the transformer, in order to determine a Description of project maximum rating on a daily basis which each transformer can sustain.

It has become apparent by comparing the output of the UK Power Networks’ model with the temperatures observed in practice, that there are some differences. The main causes for differences in modelled and observed temperature are over-simplifications of the model, and the absence of effective data for transformer and heat exchanger parameters.

Expenditure for EPN LPN SPN financial year External £0 £0 £0

Internal £172 £72 £95

Total £172 £72 £95

The costs have been allocated in proportion to the number of installed primary transformers.

External £165,677 Expenditure in previous (IFI) financial Internal £26,338 years Total £192,015

Total Project Costs Projected 2011/12 (Collaborative + £192,348 costs for UK Power Project closed external + Networks UK Power Networks)

Technological area Cyclic and emergency ratings of power transformers which form an and / or issue important consideration in reinforcement decisions. addressed by project

Project Project Residual Overall Project Benefits Type(s) of innovation Risk Score Incremental Rating involved 11.2 -1 12.2

Benefits are expected to include:  Accurate assessment of load related risk on a substation will Expected Benefits of allow UK Power Networks to confidently predict whether there Project is an unacceptable risk to supplies; and  Optimum timing of reinforcement work programmes (ability to defer spending where appropriate).

85 Expected Timescale Duration of benefit - - to adoption once achieved

Project NPV (Present Benefits – Probability of Success 40% Present Costs) x - Probability of Success

Potential for achieving Following a project review, both parties have decided not to continue expected benefits with the project as originally constructed.

UK Power Networks continues to examine load profile and past summer’s performance of all of its grid and primary transformers on an annual basis.

Project Progress UK Power Networks is also progressing internally to answer the March 2011 original questions regarding cyclic ratings and emergency rating of grid and primary transformers, and the importance or otherwise of using generic parameters or the actual parameters measured during factory test.

Collaborative Partners n/a

R&D Provider Cambridge University Engineering Department

86 Strategic Technology Programme: Module 2: Overhead Networks: 2010/2011

Description of Project A DNO research and development collaboration hosted by EA Technology.

EPN LPN SPN

External £16,157 £0 £4,826

Expenditure for Internal £1,657 £0 £495 Financial Year Total £17,813 £0 £5,321

The costs have been allocated in proportion to the length of installed overhead line.

External £227,471 Expenditure in Previous (IFI) Financial Internal £27,230 Years Total £254,701

Total Project Costs Projected 2011/12 External £48,410 (Collaborative + £330,992 Internal £4,500 External + costs for UK Power Total £52,910 UK Power Networks) Networks

The Module 2 programme for budget year 2010/11 aimed to optimise overhead network design, improve operational performance, maximise potential benefits, improve financial performance, and minimise risk associated with overhead networks, whilst having due regard for the environment and energy efficiency. The programme also aimed to deliver Technological area continuous improvement in terms of safety and environmental performance and / or issue of the overhead network to meet the individual business requirements of addressed by project Member Companies. Several of the projects contribute to the industry’s knowledge of variation in climate change.

A full list of projects within the programme can be made available on request. Updated information can be found at: https://www.stp.uk.net

Incremental, Project Benefits Project Residual Overall Project Type(s) of innovation Tech Transfer, Rating Risk Score involved Significant, Radical 16 9 25

The projects have the potential to deliver a number of benefits:  Improvements in network reliability by identifying root causes of faults and developing solutions.  Safe early detection of potential defects that can then be repaired in a planned and timely fashion.  Cost effective and early identification of damaged insulators and Expected Benefits of discharging components, which if not addressed would result in Project faults.  Development of tools, technology and techniques to reduce risk or cost, or to increase speed of capital deployment of Member Company programme delivery.  A better understanding how overhead line assets perform in service which can be used to determine the overall asset management policy.

87  Reduce levels of premature failure of assets.  Avoid redesign, reconstruction or refurbishment of overhead lines where this is driven by a perceived need to increase ratings or strengthen lines, and is required to conform with existing standards but which may be unnecessary.  Co-operation between European countries in the development of forecasting methods of atmospheric icing and for the exchange of forecasting tools.  Comparison of new covered conductor with known performance of older types.  Increasing scientific understanding of processes and climatic conditions leading to icing.  Extend the service life of poles and reduce potential levels of failures.  Reduce lifetime costs by the appropriate use of alternative materials.  Improved methodology for determining conductor ratings will provide greater confidence.  Positive impact on environmental performance and many have positive impacts on safety.  Give Members a better understanding of novel conductors for new-build or re-conductoring lines that gives lower capital cost, minimum visual impact, and environmental acceptance.

Expected Timescale to Range 1-5 years – Duration of benefit Range 3-5 years – adoption dependent on project once achieved dependent on project

Project NPV = (PV Range 50-95% – Probability of Success Benefits – PV Costs) x £40,000 dependent on project Probability of Success

A number of projects involve new technical development, for example software design tools, and will therefore take some time to come to fruition. Other projects were looking at better ways of improving the operational Potential for achieving performance, management and reliability of Overhead Networks, by expected benefits minimising the impact on the environment and the safety of both the operators and the public, in a manner that could be implemented straight away.

A number of highlights are provided below: A spreadsheet to calculate conductor temperature (OHTEMP) (10/11):  OHTEMP is a spreadsheet tool that calculates conductor temperature that is carrying a specified current under specified ambient conditions.  OHTEMP is completely deterministic: it simply calculates conductor temperature for a given current. Thus there is no need Project Progress to to invoke any probabilistic conversion factors to translate March 2011 calculated current at design conditions into exceedence-based ratings. Development of a probabilistic wind and ice map for UK – Project strategy & related interfaces (10/11):  The final outcome of this work is to develop new wind/ice loads which are expected to be less onerous than those predicted by BS 8100 and further can be used to update BS EN 50341 and BS EN 50423 standards.

ScottishPower Energy Networks, Scottish and Southern Energy, Electricity Collaborative Partners North West, Western Power Distribution, CE Electric UK, ESB Networks

R&D Providers EA Technology

88 Strategic Technology Programme: Module 3: Cable Networks: 2010/11

A DNO research and development collaboration hosted by Description of project EA Technology.

EPN LPN SPN

External £11,523 £7,071 £7,595

Expenditure for Internal £947 £581 £624 financial year Total £12,470 £7,652 £8,219

The costs have been allocated in proportion to the length of installed underground cable.

External £259,713 Expenditure in previous (IFI) financial Internal £26,866 years Total £286,579

Total Project Costs Projected 2011/12 External £58,659 (Collaborative + £378,325 costs for UK Power Internal £4,500 external + Networks Total £ 63,159 UK Power Networks)

The STP Cable Networks programme for budget year 2010/11 aimed to optimise underground cable network design, improve operational performance, maximise potential benefits, improve financial performance and minimise risk associated with underground cable networks, whilst having due regard for the environment and energy efficiency. The programme also aimed to prevent cable failure modes and to deliver Technological area continuous improvement in terms of safety and environmental performance and / or issue of all aspects of the underground cable network to meet the individual addressed by project business requirements of Member Companies.

Several of the projects contribute to the industry’s knowledge of variation in climate change.

A full list of projects within the programme can be made available on request. Updated information can be found at: https://www.stp.uk.net

Incremental, Project Benefits Project Residual Overall Project Type(s) of innovation Tech Transfer, Rating Risk Score involved Significant, Radical 14 8 22

The projects have the potential to deliver a number of benefits::  Use of an effective tool to improve the leak management of fluid filled cable circuits. Reducing the risk of potential costly failures.  Successful and practical methods for sealing ducts containing triplexed cable. Expected Benefits of  A test that truly measures the mechanical robustness of a joint Project with an understanding of the performance between “green” resin filled joints and conventional PU filled joints. This could result in significant cost benefit.  Alternatives to current design and installation practices which offer benefits in lower lifetime cost, higher performance (e.g. increased ratings).

89  Reduce risk in environmentally sensitive areas.  A reduction in the number of accidents / incidents so increasing safety of staff and the public.  Reduce excavation required in locating leaks from fluid-filled cables, reduce the times and costs of leak location, and also reducing outage times.  A reduction in digging, causing less disruption to the public, reducing impact on the environment and avoiding disposal of soil to landfill.  Offset future increases in CAPEX and OPEX.  CI/CML savings per connected customer.  Reduce cable purchase costs.  Enforce Network resilience.  Implement strategies for reducing cable failures, resulting from excessive forces.  Reduction in number of cable faults.  Reduce design costs.

Expected Timescale to Range 1-2 years – Duration of benefit Range 3-5 years - adoption dependent on project once achieved dependent on project

Project NPV = (PV Range 45-100% – Benefits – PV Costs) Probability of Success £40,000 dependent on project x Probability of Success

A number of projects involve new technical development, for example software design tools, and will therefore take some time to come to fruition. Other projects were looking at better ways of improving the operational performance, management and reliability of cable networks, by minimising Potential for achieving the impact on the environment and the safety of both the operators and the expected benefits public, in a manner that could be implemented through changes to engineering policy.

The STP has also delivered a number of notable innovations since its inception.

A number of highlights are provided below: Implications of Climate Change for Cable Systems: Effect on Cable Rating (10/11): The effects of climate change driven by high emissions on cable ratings and losses are modest, but significant. Changes in temperature may have the effect of reducing summertime in-soil ratings by 1.5 to 5% in the 2050s and 2.5 to 8.5% in the 2080s. The highest figures are associated with factors such as large cable size, high dielectric loss, low maximum conductor temperature and soil drying out (noting that the percentages calculated for soil drying out. Project Progress to March 2011 Performance Evaluation of Plastic Smoothed Walled and Corrugated Ducting Installed in Trefoil Formation: Evaluation of Results (10/11): 1. The results show that both types of duct perform satisfactorily in trefoil formation and support the conclusions of S3155. There is no compelling evidence for changing from the black corrugated duct (HDPE) to the red smooth wall duct (uPVC). 2. There is broad agreement between the experimental results and the analytical CRATER model. This work indicates that numerical modelling provides a complementary technique which improves understanding and visualisation of the phenomena involved. STP Members should consider the development of a more advanced numerical model that can be applied to support CRATER and improve predictions of the performance of buried ducting.

90

Comparison of Processes for the treatment of Redundant Fluid Filled Cables: Analysis of Cable Samples (10/11): 1. Once the majority of the oil is recovered from the cable being cleaned there is no need to have extended cleaning times, since they result in very little additional oil removal from the insulating papers. 2. The use of either nitrogen or compressed air on its own is considered to be of limited use.

ScottishPower Energy Networks, Scottish and Southern Energy, Electricity Collaborative Partners North West, Western Power Distribution, CE Electric UK, ESB Networks

R&D Providers EA Technology

91 Strategic Technology Programme: Module 4: Substations: 2010/11

Description of Project A DNO research and development collaboration hosted by EA Technology

EPN LPN SPN

External £13,101 £4,011 £9,625

Expenditure for Internal £1,054 £323 £775 Financial Year Total £14,156 £4,333 £10,400

The costs have been allocated in proportion to the number of primary substations.

External £240,122 Expenditure in Previous (IFI) Financial Internal £24,999 Years Total £265,121

Total Project Costs Projected 2011/12 External £42,860 (Collaborative + £341,617 costs for UK Power Internal £4,500 External + Networks Total £47,360 UK Power Networks)

The STP Substations programme for the budget year 2010/11 aimed to improve operational performance, maximise potential benefits, improve financial performance and minimise risk associated with substation assets whilst having due regard for the environment and energy efficiency. The projects aimed to provide cost effective solutions to increase reliability and Technological Area deliver continuous improvement in terms of safety and environmental and / or Issue performance of existing and future substation assets, to meet the individual Addressed by Project business requirements of Member Companies.

A full list of projects within the programme can be made available on request. Updated information can be found at: https://www.stp.uk.net

Project Benefits Project Residual Overall Project Type(s) of Innovation Incremental, Rating Risk Score Involved Tech Transfer, Significant, 16.5 9.5 26.0 Radical

The projects have the potential to deliver a number of benefits:  Increased reliability and continuous improvement in terms of safety and environmental performance of existing and future substation assets.  Collaborative evaluation of battery installations and operational practice to ensure a safer and more reliable network.  CI/CML savings per connected customer. Expected Benefits of  Optimising safety and environmental requirements for management of Project insulating oils and SF6.  Technical liaison with International Utilities to share new technology and failure modes.  Offset future increases in CAPEX and OPEX.  Development of condition based assessments, or tests, to determine asset condition.  Preventing failures of oil-filled equipment, tap changers, earth

92 switches will improve safety and avoid unnecessary scrapping of serviceable components, which will alleviate environmental impact.  Extend serviceable life of switchgear and transformers.  Further develop technical understanding of protection system maintenance requirements.  Understand the degradation and failure processes of substation plant and equipment, and quantify the risks associated with those processes.  Further develop technical understanding of operational staff in complex electrical issues.  Mitigate risk to environment.  Increased safety of staff and public by reducing risk of fire and the number of accidents / incidents.  Reduce lifetime costs and improve functionality by the appropriate use of new technology.

Expected Timescale to Range 1-4 years – Duration of benefit Range 1-6 years – Adoption dependent on project once achieved dependent on project

Project NPV = (PV Range 30-95% – Benefits – PV Costs) Probability of Success £30,000 dependent on project x Probability of Success

A number of projects involve new technical development, for example tap changer monitor, and will therefore take some time to come to fruition. Other projects were looking at better ways of improving working, the performance and reliability of Substation plant, maintenance regimes, Potential for Achieving minimising the impact on the environment and the safety of both the expected Benefits operators and the public for Asset Managers, in a manner that could be implemented through changes to engineering policy.

STP has delivered a number of notable innovations since its inception.

A number of highlights are provided below: Protection Testing and Maintenance Practices: Incorporating NIE & MEA: Additional Research (10/11):  A remote timed trip test provides a cost effective means of regularly confirming the availability of the circuit-breaker and tripping supplies.  A trip test using secondary injection, as opposed to a functional trip by mechanical intervention on the relay, is considered best practice for in-attendance trip testing.  Wiring IR testing of ac circuits only and use of a 500V Megger is Project Progress to considered to be able to uncover the majority of issues with minimum March 11 risk of damage to other components.

Research and Development of a Test Procedure to Cost Effectively Determine the Mechanical Strength of Transformer Paper Insulation (10/11):  The study has identified Tear Index (tear strength divided by paper grammage) offers an alternative to the use of degree of polymerisation values that is a cost effective and reliable method of identifying the transformer paper condition.

There are also number of single stage projects that have already identified Project Progress to potential benefits and opportunities for further innovative technical March 11 (Continued) development work. A small selection of these are provided below:

93

Evaluation of Fire Mitigation Techniques in Secondary Distribution Substations, rated at 11kV and below (10/11):  IEC 61936-1 is a good starting point for integrating protective fire measures into a substation design. IEC 61936-1 specifies clearances and fire ratings of materials which can be used in a design but it does not take precedence over local laws or regulations. It is therefore important that local laws and regulations are reviewed and where necessary applied before the design criteria specified in IEC 61936-1 is considered.  Fire suppression systems can be hazardous to human life and their use should be risk assessed. The requirements for maintenance should also be reviewed to ensure equipment is in correct working order and the risk of inadvertent discharge minimised.

Technical Evaluation of Common Industry Approach to Battery Charger Installations (10/11):  The consequences of a battery failure are high and though the incidence is low there is great incentive to introduce measures to avoid them. Companies should consider the case for a low cost, limited functionality Battery Management Systems that provides an alarm when there has been or is about to be an outright failure of a battery or cell.  If quick charging is required constant current or constant-constant voltage methods offer adequate solutions.

ScottishPower Energy Networks, Scottish and Southern Energy, Electricity Collaborative Partners North West, Western Power Distribution, CE Electric UK, ESB Networks

R&D Providers EA Technology

94 Strategic Technology Programme: Module 5: Networks for Distributed Energy Resources: 2010/11

Description of project A DNO research and development collaboration hosted by EA Technology.

EPN LPN SPN

External £12,241 £4,845 £8,415

Expenditure for Internal £1,033 £409 £710 financial year Total £13,273 £5,254 £9,125

The costs have been allocated in proportion to the amount of distributed generation (DG) in each license area.

External £245,995 Expenditure in previous (IFI) financial Internal £24,883 years Total £270,878

Total Project Costs Projected 2011/12 External £51,434 (Collaborative + £355,212 costs for UK Power Internal £5,000 external + Networks Total £56,434 UK Power Networks)

The STP Networks for Distributed Energy Resources programme for budget year 2010/11 aimed to maximise potential benefits and reduce costs and risks associated with facilitating the design, development and operation of networks for the integration of low carbon technologies into Technological area future network designs, whilst having due regard for the environment and and / or issue energy efficiency. The programme also aimed to cost-effectively improve addressed by project the operational efficiency and business performance of Member Companies within prevailing regulatory constraints. A full list of projects within the programme can be made available on request. Updated information can be found at: https://www.stp.uk.net

Incremental, Project Benefits Project Residual Overall Project Type(s) of innovation Tech Transfer, Rating Risk Score involved Significant, Radical 13.5 8.5 22

The projects have the potential to deliver a number of benefits:  Investigate distributed generation connection methods without undue reinforcement, while at the same time improving supply quality by reducing CMLs and voltage unbalance.  Positive impact on environmental performance and many have positive impacts on safety.  Increased understanding between all Member Companies on Expected Benefits of technical, commercial and regulatory issues and to develop effective Project solutions to these issues.  Developing understanding of the implications of connecting low carbon technologies to the distribution network in terms of safety, design, reliability, security and power quality.  Where possible, try and optimise the Government’s low-carbon strategy and accommodate the likely growth of DG.  Improved management of the implications of connecting distributed resources to the distribution network in terms of the statutory,

95 regulatory and commercial frameworks.  Investigating low carbon network designs and plan transition from passive to active networks.  Improve power quality issues due to dynamic load change.  Enabling the development of strategies to manage PQ levels and customer expectations.  Reduction in losses for DNOs.  Highlight the issues and benefits of Smart Grids, Smart Meters and Active Network Management Systems, ultimately improving CMLs.  Significant benefits in terms of enhanced knowledge and awareness of overseas best practice in DG system integration, which can be applied, as appropriate in the UK.  Ensure that all participants optimise network design, financial and operational performance as the levels of storage, managed-demand and distributed generation increase on the distribution networks.  Developing and emerging distributed generation, demand-side management, storage technologies.

Range 1-3 years – Duration of benefit once Range 2-5 years – Expected Timescale to adoption dependent on project achieved dependent on project

Project NPV = (PV Range 50-100% – Probability of Success Benefits – PV Costs) x £30,000 dependent on project Probability of Success

There are a huge variety of projects within the 2010/11 work programme for Module 5. A number of these projects are scientific based and will require further research and development to achieve improvements in operational performance and integration into the Network Operators’ business environment. Projects in these areas are mainly stages of much larger multi-stage projects and require further work to optimise network design, financial and operational performance from which the customer and stakeholders will benefit.

Potential for achieving Other projects are looking at better ways of improving working and expected benefits productivity for network planners, in a manner that could be implemented straight away.

Collectively, the 10/11 work programme demonstrates the development of the technical understanding in relation to connecting and integrating low carbon technologies onto the distribution network; in terms of safety, design, reliability, security and power quality.

STP has also delivered a number of notable innovations since its inception.

96 A number of highlights are provided below: Correlation of Wind Speeds over 1-20km (10/11):  The probability reduction ratios r(1,20) for individual pairs of sites show a distinct linear variation with height difference between the two sites, but there is no discernible variation with distance between sites.  If we could confidently apply this probability reduction ratio to the exceedence curve behind the P27 ratings, the single circuit ratings could be raised by about 13%.

 Further work, preferably using 6-minute weather data from pairs of sites within 20 km of each other, is recommended to clarify the Project Progress to relationship between the 3-hour and 6-minute probability reduction March 2011 ratios, in order improve the accuracy and confidence of the possible ratings enhancements suggested by this work.

Standardising the Control and Communications Interface for DG Connections (10/11):

 Whilst there is progress in developing standards for interoperability and communications there is much less progress in developing reference architectures or a strategic plan for how ANM solutions might be replicated or at what level control should take place.  The definitions and diagrams of ANM structures used to develop interoperability standards could be adapted for this purpose. However, much of the information required for the work on architectures and co-ordinating control will need to be learnt from practical trials. At present, there is insufficient experience of how ANM can be implemented. To collate the lessons learnt, each ANM Project Progress to solution could be mapped onto an initial agreed architecture. The March 2011 lessons learnt in turn would help refine the architecture. At the practical level, the Danish Cell Concept is a useful means to develop ANM in a more strategic manner on the ground.  These activities should help demonstrate how the regulatory framework needs to be adapted to enable more strategic planning and encourage new players such as virtual power plants and microgrids.

ScottishPower Energy Networks, Scottish and Southern Energy, Electricity Collaborative Partners North West, Western Power Distribution, CE Electric UK, ESB Networks

R&D Providers EA Technology

97 Collaborative ENA R&D Programme

The Energy Networks Association (ENA) represents all the UK network Description of Project operators. Several projects have been initiated by the ENA R&D Working Group and have been funded through the IFI.

Expenditure for Financial EPN LPN SPN Year External £26,259 £16,781 £16,792

Internal £5,408 £3,456 £3,458

Total £31,666 £20,237 £20,250

The costs have been allocated in proportion to the number of customers connected to each licensed area.

External £462,367 Expenditure in Previous (IFI) Financial Years Internal £61,861

Total £524,227

Total Project Costs Projected 2011/12 External £130,000 (Collaborative + External + £ 731,986 Costs for UK Power Internal £5,000 UK Power Networks) Networks Total £135,000

The projects listed below address issues which have been identified by the ENA Working Groups as significant issues requiring technical investigation and development:  Harmonic Impedance Modelling – The project addresses the detailed modelling of cable and overhead line components, to develop cable models appropriate for distribution networks.  Earthing Project – The aim is to develop new techniques to assess the impact of lower voltage earth electrodes on higher voltage ‘hot zones’ and to measure the resistance of distribution substation earth systems.  Climate Change and Network Resilience Project – The objective of this project was to investigate whether the electricity (both Technological Area and/or transmission and distribution) networks’ risk to weather-related Issue Addressed by Project faults may change in the future as a result of climate change.  Smart Metering Studies – the ENA commissioned Engage Consulting to undertake a comprehensive analysis of UK Power Networks’ requirements for a smart metering system for electricity and gas. This project was split into four work streams:  WS 1 – ENA Smart Metering System Requirements.  WS 2 – Development of Appropriate Use Cases.  WS 3 – Performance Standards and Communication requirements.  WS 4 – Privacy and Security Considerations. A study has been carried out by Imperial College London to investigate the benefits of advanced Smart Metering for Demand Response.

98 Project Project Residual Overall Project Benefits Type(s) of Innovation Incremental Risk Score Involved Innovation Rating

6.2 -10 16.2

These projects have the potential to provide a wide range of benefits. In some cases, they will help to understand key asset-related issues and Expected Benefits of allow designs to be altered to address them. In other cases they will Project allow us to better understand risks to our network, whether from climate change or changes in demand. The smart metering project is already having a valuable input to the overall smart metering consultations.

Expected Timescale to Duration of Benefit Year 2010 10 – 20 Years Adoption Once Achieved

Project NPV (Present Benefits – Probability of Success 75% Present Costs) x £100,000 Probability of Success

Work on the climate change and network resilience project will assist DNOs to quantify the long term relationship between climate change and network faults, and the vulnerability and exposure of the network to Potential for Achieving these faults. Some of the outputs from this study have been factored Expected Benefits into the companies’ recent Climate Adaptation reports to DEFRA.

The remaining projects are still demonstrating their potential to achieve the benefits expected.

Harmonic Impedance Modelling One of the deliverables from the original project was a proposed revision of G5/4 to introduce a new simplified Stage 3A methodology for simple and small low harmonic connections. One outstanding question required further investigation and this was the proposed 75% criteria for Stage 3A compliance. The concern was that the selection of 75% was somewhat arbitrary and was only based on the existing Stage 2 criteria.

This investigation is currently underway and it is anticipated that the results of the investigation will be published in the autumn 2011.

Climate Change and Network Resilience Project Project Progress This project is now complete. In this project the DNOs have considered March 2011 how the frequency of weather-related faults on the UK transmission and distribution electricity networks may change in the future as a result of climate change. The methodologies applied to the various types of weather-related faults are detailed in the study report.

This project has involved close collaboration between climate scientists and industry experts. The scientific insights that can be gained from appropriate use of climate projections have been combined with the industry experts' understanding of the relevant thresholds, procedures and actions involved in managing the impact of weather and climate on the electricity network. The result is an assessment of projected future risk that can be a useful tool to the electricity sector in developing climate adaptation strategies for the future.

99 Earthing Project – HV/LV Earthing Transfer This project is nearing completion. A new calculation method has been developed that more accurately approximates transfer potential between HV and LV earthing systems in distributed LV networks (e.g. PME in the UK). The new calculation method accounts for the beneficial reduction in LV transfer potential provided by larger LV electrodes which are located further away from the HV substation (as previously demonstrated by measurement). The new method is in agreement with results from detailed simulation software (uniform soil).The work is currently being used to develop new guidance/calculation tools for UK standards. LV earthing design practice will need to be reviewed. The work suggests that LV electrode should be installed in parts of the network furthest from the HV electrode, e.g. at the end of LV feeder cables. Work is progressing to evaluate the new calculation method with different arrangements, soil resistivity, etc.

Cable Fault Calculation The second part of this project was to develop and deliver an interactive tool that could assess the impact of cable sheath sizing, material and connections upon the safety of electrical power installations.

When an earth fault occurs, the resulting current must return to its source via metallic routes (such as a cable sheath) and through the soil/ground. The latter part flows through the local earthing system and creates a temporary elevated potential, called the Earth Potential Rise (EPR). This in turn can cause equipment damage and potentials that create a shock risk to nearby people and animals.

In the new European Earthing Standard EN50522 and IEC 61936-1, an understanding of the role of the cable sheath in returning some of the earth fault current is one of the factors that determine whether a ‘Global Earthing System’ exists.

In order to analyse such circuits effectively a spreadsheet based routine has been developed for 11kV distribution cables. The first step was to calculate the necessary cable parameters to a high degree of accuracy. A number of representative circuits were subsequently analysed in detail using software packages, numerical methods and formulae. Finally, formulae of sufficient accuracy were used in a spreadsheet routine. This allows the effect of important variables upon the ground return current to be calculated. Its use has already led to new ideas about the design of earthing systems.

The aim is to develop new design rules and policies and extend the spreadsheet to cover a wider range of circuits (such as at higher voltages) and other parts of the earthing calculations carried out at the design stage. The findings from this study will be presented at the 2011 CIRED Conference.

Smart Metering Studies Comprehensive studies into both Smart Metering and Smart Metering for Demand Response and their subsequent reports have been published and are now publically available on the ENA website.

100 National Grid, ScottishPower Energy Networks, Scottish and Southern Collaborative Partners Energy, Electricity North West, Western Power Distribution, CE Electric UK

TNEI, Engage Consulting Limited, Imperial College London, Met Office, R&D Providers EA Technology Ltd, Earthing Solutions, SEDG

101 Network Risk Management (closed)

The aim of this project was to develop algorithms for calculating the risk to satisfactory network operation from the continued use of the elements of a distribution system. The calculations take into consideration significant levels of uncertainty surrounding both the condition of the individual assets and the overall configuration of the network. The measure of risk may characterise network performance in the near future.

Driven by consumer demands and cost drivers, DNOs are looking to make their networks more active. The use of automated switching, Description of Project remote sectionalising, distributed generation, demand side integration and storage elements will allow network operation to become more flexible and more responsive to system conditions, which will increase the complexity of network operation, forcing system operators to be more active and make more operational decisions.

The project developed new methodologies to enable formal understanding of the criticality of different operational configurations and the accuracy with which network parameters must be specified. In addition, it illustrated the value of an explicitly predictive indicator of the suitability of proposed changes in system operation.

Expenditure for EPN LPN SPN Financial Year External £60,565 £38,705 £38,730

Internal £5,186 £3,314 £3,316

Total £65,751 £42,019 £42,047

The costs have been allocated in proportion to the number of connected customers.

External £374,060 Expenditure in Previous (IFI) Internal £31,327 Financial Years Total £405,388

Total Project Costs Projected 2011/12 (Collaborative + £556,578 costs for UK Project closed External + Power Networks UK Power Networks)

This project has addressed:  The formulation and implementation of algorithms to provide, in near real-time, an assessment of the risk or vulnerability of a section of UK Power Networks’ distribution system into the near future.  Drivers for measures of network risk. Technological Area  Provision of the value of a measure of risk for guiding network and /or Issue operation. Addressed By Project  Investment strategies for improving quality of supply.  Customer Focused Quality of supply – location and degree of exposure of load points to significant risk of poor performance.  Evaluating of risk levels associated with construction outages in EHV substations – Potential high risk exposure to consumers and QoS penalties.

102  The viability of using active network management processes, such as demand side management controls, the presence of storage and CHP to reduce network vulnerability.

Project Benefits Project Residual Overall Project Type(S) of Innovation Significant Rating Risk Score Involved 10.4 6 4.4

A number of areas were highlighted in which a more rigorous, formal approach to considering options may be beneficial. A balance needs Expected Benefits of to be struck between engineering experience and information Project requirements for rigorous simulation and the incremental benefits of some of the options that may be identified by these formal tools.

Expected Timescale Duration of benefit Year 2011 20 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 75% Present Costs) x £ 200,000 Probability of Success

A number of tools and models were reviewed in March. These did show levels of risk associated with different types of distribution Potential For network. This project has developed a framework for evaluating Achieving Expected running arrangements. This has added a level of formalisation to Benefits outage planning and Network strategy engineers who can choose options to increase flexible network design.

Construction Outage Risks – Developed prototype techniques for evaluating of risk levels associated with construction outages in EHV substations considering with uncertainty in failure rates, repair times and level of transfer capability. Quantification of the Impact of Risk Mitigation Measures  Network refurbishment and network maintenance; and  Investment in HV network flexibility (optimal deployment in condition monitoring devices, switchgear and automation). Project Progress Reliability performances of HV networks were explained and March 2011 compared within and across DNOs. Network performance differences can be effectively measured and linked to differences in physical network parameters. Investment proposals can be developed to match improved network performances. Customer Focused Quality of Supply  Demonstrated significant variability in quality of supply experienced by customer and risk of poor performance.  Accessed the influence of future load and demand side management techniques on risk performance.

Collaborative Partners n/a

R&D Provider Imperial College London

103 Active Distribution networks with full integration of Demand and distributed energy RESourceS (ADDRESS)

The project aims to deliver a comprehensive commercial and technical framework for the development of ‘Active Demand’ in the smart grids of the future. ADDRESS started in June 2008 and is investigating how to effectively stimulate the participation of domestic Description of Project and small commercial consumers in the power system markets. The project also addresses the provision of services to different power system participants. ADDRESS is European Commission funded FP7 project.

Expenditure for EPN LPN SPN Financial Year External £0 £0 £0

Internal £149 £95 £95

Total £149 £95 £95

The costs have been allocated in proportion to the number of customers connected to each licence area.

External £0 Expenditure in Previous (IFI) Internal £11,251 Financial Years Total £11,251

Total Project Costs Projected 2011/12 External £0 (Collaborative + € 16,000,000 costs for Internal £1,000 External + UK Power Total £1,000 UK Power Networks) Networks

The project aims to develop new concepts, strategies and Technological Area architectures for services provided by demand and distributed energy and / or Issue resources (DG, RES and storage) on distribution grids. This entails a Addressed by Project full integration and market-based exploitation of the flexibilities of the distributed energy resources of the distribution network.

Project Project Residual Overall Project Type(S) of Innovation Benefits Incremental Risk Score Involved Rating

11.2 -2 13.2

ADDRESS will develop technical solutions both for the consumers’ Expected Benefits of premises and at a power system level. The solutions will enable Project Active Demand (AD) and allow real-time response to requests from markets and/or other power system participants.

Expected Timescale Duration of benefit Year 2015 10 Years to Adoption once achieved

Project NPV Wide-scale adoption of (Present Benefits – active demand could Probability of Success 75% Present Costs) x deliver benefits in the Probability of order of millions of

104 Success pounds.

A key concept within the project is that the ‘Energy box’ which acts as a physical gateway in the home to manage the resources from e.g. Potential For white goods. This concept would need to be commercialised in order Achieving Expected for the benefits to be realised. Capable partners are involved in the Benefits consortium with these commercialisation requirements in mind. The strong presence of DNOs in the consortium means that data interfaces and flows match existing legacy systems as far as possible.

The main activities this year have concentrated on:  Algorithms for aggregators, customers and their responsive equipment, the development of Local Energy Management hardware with control algorithms. Project Progress  A description of market mechanisms (regulations, economic March 2011 incentives and contract structures) which enable active demand participation; and a guide to develop smart grid communication infrastructure. All these have assisted in the definition of the trials planned for this final year in Spain, France and Italy.

ADDRESS is an Integrated Project supported by the European Collaborative Partners Commission under the 7th framework programme. The project website is: www.addressfp7.org

ENEL Distribuzione S.p.A. Landis & Gyr, Electricité de France S.A. Tecnalia Iberdrola Distribución Electrica RLtec ABB Switzerland Ltd. Corporate Electrolux Home Products Research Corporation N.V. Universidad Pontificia Comillas Università degli studi di Cassino University of Manchester Universita` degli studi di Siena R&D Providers VTT, Technical Research Centre ZIV Pmas C S.L. of Finland Current Technologies VITO NV International GmbH Ericsson España, S.A.U. ENEL Distributie Dobrogea Alcatel Italia S.p.A. Philips KEMA Nederland B.V. Consentec Vattenfall ENEL Ingegneria e Innovazione UK Power Networks

105 Transformer Design for FR3

This project is assessing the use of FR3 vegetable oil, manufactured by Coopers, as an alternative to mineral oil in large power transformers. FR3 is biodegradable and has a considerably higher Description of Project flash-point than mineral oil, however its increased viscosity and oxidisation rate means that additional design work is needed in the manufacture of the transformer.

Expenditure for EPN LPN SPN Financial Year External £41,662 £0 £0

Internal £6,512 £0 £0

Total £48,174 £0 £0

The costs have been allocated to the EPN licence area where the transformer is in service.

External £1,141,860 Expenditure in Previous (IFI) Internal £105,387 Financial Years Total £1,247,247

Total Project Costs Projected 2011/12 External £24,000 (Collaborative + £ 1,321,856 costs for UK Power Internal £2,000 External + Networks Total £26,000 UK Power Networks)

The demonstration aims to: Technological Area  Evaluate the use of FR3 as an environmentally-friendly and and / or Issue safer alternative to mineral-oil insulation of 132kV transformers. Addressed by Project  Assess the reaction of the plant components to FR3 and the comparative ageing of transformers with FR3 versus mineral oil.

Project Project Residual Overall Project Benefits Type(s) of Innovation Risk Score Incremental Rating Involved

11.2 3 8.2

Expected benefits include:  Improved safety for staff and public in the event of failures. Expected Benefits of  Reduced clean-up / disposal costs of insulating oil. Project  Reduced carbon-footprint of operations.  Life-extension of transformer insulating paper.

Expected Timescale Duration of benefit 2012 20 years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 75% - Present Costs) x Probability of

106 Success

In the first phases of the project, FR3 has been shown to have good potential as design changes to accommodate the oil are relatively straightforward. The transformers have now been in operation for Potential for Achieving over 24 months without any issues. Expected Benefits Further academic research has shown potential performance and life- extension improvements are possible, and it is hoped field trials will confirm this.

A 90MVA FR3-filled transformer has been operating alongside an identical mineral-oil filled transformer for over 24 months. An MS2000 remote monitoring system has been used to collect a range of metrics on transformer operation and performance.

There have been some issues with the winding temperature readings from the mineral-oil transformer. These were identified as resulting from faulty internal connections or damaged fibre-optic temperature probes embedded in the windings.

Regular analysis of the remaining collected data is continuing, with Project Progress early results so far confirming previous research and findings. With March 2011 similar loading, top oil temperature has been approximately 5ºC higher in the FR3-filled transformer due to the higher viscosity of the medium.

Further oil samples and analysis are planned in order to compare characteristics further, such as the difference in ageing of paper insulation and the overall thermal performance of the transformers.

Additional work is also underway in order to understand the implications on the supply-chain and maintenance/disposal processes if FR3 were to be introduced as an alternative.

Collaborative Partners n/a

Areva University of Manchester R&D Provider Coopers Power Systems Monash University Brush Transformers

107 Vacuum Tap Changer (closed)

This project sought to investigate the development of a vacuum bolt- on type tap-changer based on the existing AT type design, a bolt-on model widely used within UK Power Networks with many advantages Description of Project over the in-tank type.

The project scope covered the design, manufacture, KEMA type testing and fitting of a prototype on a new transformer for field service.

Expenditure for EPN LPN SPN Financial Year External £0 £0 £0

Internal £997 £417 £551

Total £997 £417 £551

The costs have been allocated in proportion to the number of primary transformers supplying the distribution network.

External £254,698 Expenditure in Previous (IFI) Internal £27,793 Financial Years Total £282,491

Total Project Costs Projected 2010/11 (Collaborative + £284,463 costs for UK Power Project closed External + Networks UK Power Networks)

The project was investigating development of a bolt-on vacuum Technological Area insulated on-load tap-changer for power transformers, with a view to and / or Issue addressing the issues of high maintenance requirements and safety- Addressed by Project risks associated with of oil-insulated types.

Project Project Residual Overall Project Benefits Type(s) of innovation Risk Score Radical Rating involved

17 2 15

Benefits expected included:  Reduced maintenance requirements and improved network Expected Benefits of availability. Project  Reduced risks associated with failure, relative to oil-insulated tap-changers.

Expected Timescale Duration of benefit - - to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 0% Present Costs) x - Probability of Success

108 Potential for Achieving n/a – The decision was taken to terminate the project. Expected Benefits

A review of the design methodology and assessment of risks led to some early delays in the progression of the project.

Project Progress Following review with the R&D provider, it became clear there was March 2011 limited probability of success in light of raised safety concerns around other vacuum tapchanger technologies and designs. Further development to reach field-trial stage was therefore deemed non cost-effective and it was decided to terminate the project.

Collaborative Partners n/a

R&D Provider Brush Transformers

109 Recycling Excavated Material (closed)

This project was initiated in 2006 to identify ways that excavated ground works material, resulting from jointing, maintenance and new construction could be recycled. With increasing pressures on landfill use, the project investigated and implemented changes in the management and reuse of excavated materials by UK Power Description of Project Networks to reduce tonnage of material sent to landfill each year.

A second phase of the project concentrated on sustainable working practices. By taking a holistic view of streetworks activities Phase 2 delivered a tool that determines the most sustainable approach to the task.

Expenditure for EPN LPN SPN Financial Year External £0 £0 £0

Internal £152 £90 £98

Total £152 £90 £98

The costs have been allocated in proportion to length of installed underground cable.

External £95,137 Expenditure in Previous (IFI) Internal £23,636 Ffinancial Years Total £118,773

Total Project Costs Projected 2011/12 (Collaborative + £119,106 costs for UK Power Project closed External + Networks UK Power Networks)

Phase 1 of this project demonstrated that excavated materials could be recycled at one of several recycling facilities in the UK to meet Highways Authority requirements. The recycled materials can be classed as replacement type 1 material and can be used to backfill streetworks. Technological Area

and / or Issue The Carbon Calculator developed in Phase 2 delivered a tool based Addressed by Project on the PAS 2050 standard and it can be used to take a holistic view of planned work. The tool aims to determine the most sustainable method of work on a job by job basis, and has the aims of implementing sustainable working and overall reduction in greenhouse gas emissions.

Project Benefits Project Residual Overall Project Type(s) of Innovation Rating Risk Score Significant Involved 12.2 3 9.2

Benefits are expected to include: Expected Benefits of  Reduction in the amount of material sent to landfill by 136,000 Project tonnes per year.  Reduction in excavated virgin material from around the world by

110 136,000 tonnes.  Less vehicle movement to landfill sites and gravel yards.  Less pollution on roads caused by vehicle movement.  Less traffic accidents caused by vehicle movement.

Expected Timescale Duration of benefit Year 2011 20 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 80% Present Costs) x >£2,000,000 Probability of Success

Thanks to early initiation of Phase 1 (recycling of excavated materials) the above NPV has been achieved through savings in landfill taxation that would have been paid if UK Power Networks had been slow to act.

Potential for Achieving In a paper exercise the carbon calculator tool has been shown to Expected Benefits reduce carbon emissions. However, a clear view of all job-related carbon sources is required to use the tool accurately; full carbon source information is not currently available at the required granularity. On this basis and through lack of resource full trial and implementation of the tool has been suspended.

This project has been very successful. The primary aim of reducing excavated material sent to landfill was quickly realised and performance has continuously improved. UK Power Networks now sends less than 2.5% of its excavated material to landfill.

A paper exercise demonstrated how the carbon calculator tool could be used to design projects. The paper exercise concentrated on one of UK Power Networks streetworks contractors; they worked with UK Power Networks to provide emissions data for individual activities Project Progress typical of a project. To create a fully functioning tool, carbon March 2011 emissions data is required for each contractor, to facilitate the completion and maintenance of the Carbon Calculator tool requires significant resource that is not available at present.

If carbon emission data is completed the tool could be trialled for Capital Programme work. Instructions for the tools’ use have been generated.

The project is now considered closed.

Collaborative Partners University of Surrey

R&D Provider Not applicable

111 Lone Worker Risk Management (closed)

Following serious incidents in the past, there has been a requirement to source a technology solution to monitor the welfare of at-risk lone workers. The solution would enable them to raise an alert if required and to provide an appropriate process to render assistance should this be necessary. Over the last 12 months the Lone Worker Project Description of project has acquired third party solutions that provide support for employees who work alone in potentially risky environments and out of direct contact with other people for long periods of time. The solutions provide lone workers with a consistent and easy to access means of calling help in the event of an incident.

Expenditure for EPN LPN SPN Financial Year External £104,974 £29,671 £52,272

Internal £8,921 £2,521 £4,442

Total £113,894 £32,192 £56,715

The costs have been allocated in proportion to the length of installed circuit.

External £50,693 Expenditure in Previous (IFI) Internal £17,890 Financial Years Total £68,583

Total Project Costs Projected 2011/12 (Collaborative + £273,248 costs for UK Power Project Closed External + Networks UK Power Networks)

Technological Area and / or Issue Managing lone worker risk using technological solutions. Addressed by Project

Project Benefits Project Residual Overall Project Type(s) of Innovation Rating Risk Score Incremental involved 7 -3 10

112 The project has introduced and validated support to lone workers as follows:  A dedicated device that enables the lone worker to signal for assistance also providing an automatic call where an employee is rendered unconscious, injured by shock or fall, and therefore, incapacitated. It is capable of network ‘roaming’ to maximise communications in areas of poor Expected Benefits of coverage. Project Separate activities carried out by the business outside the scope of IFI funding have delivered the following:  A routine welfare check service that provides for scheduled communication checks at appropriate intervals in order to confirm the lone worker’s welfare.  A 24/7 monitoring, response and escalation service integrated with the technology.

Expected Timescale Duration of benefit Year 2011 10 Years to Adoption once achieved

Project NPV (Present Benefits – Probability of Success 80% Present Costs) x £ 100,000 Probability of Success

Some 470 at-risk lone workers across the entire business are now able to use the solution put in place. This provides an immediate personal protection to these people.

The benefits are:  Improved staff security. Benefits Achieved  Improved safety culture.  Mitigate the risk of prosecution following a serious incident involving an at risk lone worker.  Protection to UK Power Networks safety reputation.

To date no lone worker has had to trigger his or her device.

In July 2010 an initial deployment, conceived as a design validation, allowed lone workers to test the practical aspects of the lone worker solution. The trial was made to a representative group of 200 lone Project Progress workers in Network Operations and the Capital Programme March 2011 directorates. Following an evaluation the case to extend the use of the solution across the whole company was accepted and the business funded an additional deployment of 270 lone workers during February and March 2011.

Collaborative Partners n/a

The lone worker service is entirely provided by Skyguard Ltd. Under R&D Provider the terms of a UK Power Networks contract: www.skyguardgroup.com

113 Multiple Cable Ratings in Ventilated Tunnels (closed)

This project sought to develop improved tools for calculating ratings of multiple cable circuits installed in tunnels. Data (temperature, load and Description of Project air flow) has been collected from UK Power Networks’ tunnels, and the results have been used to verify assumptions upon which the ratings models are built.

Expenditure for EPN LPN SPN Financial Year External £13,160 £7,748 £8,492

Internal £1,247 £734 £804

Total £14,407 £8,482 £9,296

The costs have been allocated in proportion to length of installed cable.

External £12,600 Expenditure in Previous (IFI) Internal £7,594 Financial Years Total £20,194

Total Project Costs Projected 2011/12 External £0 (Collaborative + £54,665 Costs for UK Power Internal £2,000 External + Networks Total £2,000 UK Power Networks)

Technological Area and/or Issue Rating of cables in tunnels Addressed by Project

Project Benefits Project Residual Overall Project Type(s) of Innovation Incremental Rating Risk Score Involved innovation 8.6 -1 9.6

The expected benefits of this project were:  To apply improved rating methods for multiple cable circuits in tunnels. Improved prediction of cable operating limits will help to ensure that the capacity of cables is used to their maximum Expected Benefits of and that the risk of asset failure is minimised. Project  To aid maintain security of supply and improve the health and lifetime management of cable assets.  Depending on the findings, to modify the industry standard (Electra 143) upon which is based UK Power Networks cable rating tool.

Expected Timescale Duration of Benefit 1-2 years 10+ years to Adoption Once Achieved

Project NPV (Present Benefits – Probability of 75% Present Costs) x £100,000 Success Probability of Success

114 Potential for Achieving Expected Project closed Benefits

The third and final work package was completed in March 2011.

This work package demonstrated a number of improvements which can be made to the Electra 143 rating calculation, including the ability to model individual cable circuits with fully independent load characteristics (this is useful in a co-located tunnel environment where more than one voltage level of cable is installed).

In order to form a comparison with existing rating tools, models of two existing UK Power Networks tunnels were created. The model tunnels were rated using Electra 143 and the revised method, with comparison to design reference parameters from the tool currently used Crater. Comparison with the ‘equivalent cable’ method of applying Electra 143 to Project Progress such installations has shown that there is a risk of generating ratings March 2011 which would cause conductor temperatures in excess of the expected limits.

A comparison has also been formed with a design study undertaken in CRATER. It was found that the air temperatures predicted in the CRATER study were higher; however the 132kV cable circuit temperatures in the CRATER study were lower.

It would be possible to further investigate the differences in the results through closer examination of the CRATER algorithms and assumptions. The revisions to the Electra model studied within this work programme could feasibly be introduced to CRATER in later revisions of the software where the individual features would be valuable and make a non- negligible difference to the rating calculations.

Collaborative National Grid Partners

R&D Providers University of Southampton

115 Advanced Harmonic Monitoring

The purpose of the harmonic monitoring project was to establish a framework for the management of harmonics which will focus on:  A quantification of the current level of harmonics.  A quantified analysis of consequences (losses, life expectancy, Description of Project accelerated ageing).  The development of a system and strategy to manage the increasing level of harmonics.  Maximising the output of the on-going power quality programme.

Expenditure for EPN LPN SPN Financial Year External £23,320 £7,933 £18,159

Internal £2,100 £714 £1,635

Total £25,420 £8,647 £19,794

The costs have been allocated in proportion to the number of primary substations.

External £154,258 Expenditure in Previous (IFI) Internal £36,634 Financial Years Total £190,892

Total Project Costs Projected 2011/12 External £40,000 (Collaborative + Costs for £287,240 Internal £2,000 External + UK Power Total £ 42,000 UK Power Networks) Networks

Technological Area and/or Issue Harmonics and their effect on plant health and plant rating. Addressed by Project

Project Benefits Project Residual Overall Project Type(s) of Innovation Rating Risk Score Incremental Involved 11.2 -1 12.2

Identify and understand the impact of harmonics on the network:  Establish whether reducing total harmonic distortion reduces Expected Benefits of losses and frees up capacity. Project  Evaluate the impact of harmonics on the life expectancy of assets.  Evaluate the current level of third harmonic in the neutral.

Expected Timescale Duration of Benefit Year 2010 10 Years to Adoption Once Achieved

Project NPV Probability of (Present Benefits – 75% £200,000 Success Present Costs) x Probability of

116 Success

Potential for A number of pieces of Power Quality Monitoring equipment have been Achieving Expected installed. The scope of the project is being reviewed. Benefits

Following the completion of the initial phase of the project, UK Power Networks took the decision that it would be more beneficial to the industry if part of this project is funded collaboratively by a number of Distribution Network Operators.

Project Progress The scope of this project is currently being defined with a number of March 2011 interested DNOs.

UK Power Networks will make the data of installed power quality monitoring equipment available to the R&D supplier chosen to carry out the project.

Collaborative EDF R&D Partners

R&D Provider To be decided at the next stage.

117 Technology Innovation Team UK Power Networks Energy House Hazelwick Avenue Crawley West Sussex RH10 1EX